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AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON MARCH 30, 2001
REGISTRATION NO. 333-50828
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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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Amendment No. 2
to
FORM S-4
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
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CEDAR BRAKES I, L.L.C.
(Exact name of registrant as specified in its charter)
DELAWARE 4911 76-0613738
(State or other (Primary Standard Industrial (I.R.S. Employer
jurisdiction of organization) Classification Code Number) Identification No.)
1001 LOUISIANA STREET
HOUSTON, TEXAS 77002
TEL: (713) 420-2131
(Address, including ZIP code, and telephone number, including area code,
of registrant's principal executive offices)
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BRITTON WHITE JR.
1001 LOUISIANA STREET
HOUSTON, TEXAS 77002
TEL: (713) 420-2131
(Name, address, including ZIP code, and telephone number, including area code,
of agent for service)
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Copies of correspondence to:
A. ROBERT COLBY, ESQ.
CHADBOURNE & PARKE LLP
30 ROCKEFELLER PLAZA
NEW YORK, NEW YORK 10112
TEL.: (212) 408-5100
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APPROXIMATE DATE OF COMMENCEMENT OF PROPOSED SALE OF THE SECURITIES TO THE
PUBLIC: as soon as practicable after the effective date of this registration
statement.
If any of the securities being registered on this Form are being offered in
connection with the formation of a holding company and there is compliance with
General Instruction G, check the following box. [ ]
If this Form is filed to register additional securities for an offering
pursuant to Rule 462(b) under the Securities Act, check the following box and
list the Securities Act registration statement number of the earlier effective
registration statement for the same offering. [ ]
If this Form is a post-effective amendment filed pursuant to Rule 462(d)
under the Securities Act, check the following box and list the Securities Act
registration statement number of the earlier effective registration statement
for the same offering. [ ]
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THE REGISTRANT HEREBY AMENDS THIS REGISTRATION STATEMENT ON SUCH DATE OR
DATES AS MAY BE NECESSARY TO DELAY ITS EFFECTIVE DATE UNTIL THE REGISTRANT SHALL
FILE A FURTHER AMENDMENT WHICH SPECIFICALLY STATES THAT THIS REGISTRATION
STATEMENT SHALL THEREAFTER BECOME EFFECTIVE IN ACCORDANCE WITH SECTION 8(a) OF
THE SECURITIES ACT OF 1933, AS AMENDED, OR UNTIL THIS REGISTRATION STATEMENT
SHALL BECOME EFFECTIVE ON SUCH DATE AS THE COMMISSION, ACTING PURSUANT TO
SECTION 8(a), MAY DETERMINE.
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THE INFORMATION IN THIS PROSPECTUS IS NOT COMPLETE AND MAY BE CHANGED. WE
MAY NOT SELL THESE SECURITIES UNTIL THE REGISTRATION STATEMENT FILED WITH
THE SECURITIES AND EXCHANGE COMMISSION IS EFFECTIVE. THIS PROSPECTUS IS
NOT AN OFFER TO SELL THESE SECURITIES, AND WE ARE NOT SOLICITING AN OFFER
TO BUY THESE SECURITIES IN ANY STATE WHERE THE OFFER OR SALE IS NOT
PERMITTED.
SUBJECT TO COMPLETION, DATED MARCH 30, 2001
PROSPECTUS
CEDAR BRAKES I, L.L.C.
$310,600,000
OFFER TO EXCHANGE ALL OUTSTANDING 8 1/2% SENIOR SECURED BONDS DUE 2014
FOR 8 1/2% SERIES B SENIOR SECURED BONDS DUE 2014
We are offering to exchange all of our outstanding 8 1/2% Senior Secured
Bonds due 2014 for our registered 8 1/2% Series B Senior Secured Bonds due 2014.
In this prospectus, we will call the original bonds the "Series A bonds" and the
registered bonds the "Series B bonds." The Series A bonds were issued on
September 26, 2000. The terms of the Series B bonds are substantially identical
to the terms of the Series A bonds, except that we have registered the Series B
bonds with the Securities and Exchange Commission. Because we have registered
the Series B bonds, the Series B bonds will not be subject to transfer
restrictions and will not be entitled to registration rights. The Series A bonds
and Series B bonds are collectively referred to in this prospectus as the
"bonds."
THE SERIES B BONDS
- The Series B bonds will mature on February 15, 2014.
- We will pay interest on the Series B bonds semi-annually on February 15
and August 15 of each year beginning February 15, 2001 at the rate of
8 1/2% per annum.
- We may redeem the Series B bonds at any time. The redemption prices we
will pay if we do redeem bonds are specified in the prospectus under
"Description of the Bonds -- Redemption at Our Option."
- The Series B bonds are secured obligations and senior to all our current
indebtedness and future indebtedness.
- The Series B bonds will not be listed on any securities exchange or the
NASDAQ Stock Market.
THE EXCHANGE OFFER
- Subject to customary conditions, which we may waive, the exchange offer
is not conditioned upon a minimum aggregate principal amount of Series A
bonds being tendered.
- Our offer to exchange Series A bonds for Series B bonds will be open
until 5:00 p.m., New York City time, on [ ], 2001, unless we extend
the expiration date.
- You should also carefully review the procedures for tendering the Series
A bonds beginning on page 63 of this prospectus.
- You may withdraw your tenders of Series A bonds at any time prior to the
expiration of the exchange offer, unless we have already accepted your
Series A bonds for exchange.
- If you fail to tender your Series A bonds, you will continue to hold
unregistered securities and your ability to transfer them could be
adversely affected.
- The exchange of Series A bonds for Series B bonds in the exchange offer
will not be a taxable event for U.S. federal income tax purposes.
YOU SHOULD CAREFULLY CONSIDER THE RISK FACTORS BEGINNING ON PAGE 13 OF THIS
PROSPECTUS BEFORE PARTICIPATING IN THE EXCHANGE OFFER.
NEITHER THE SEC NOR ANY STATE SECURITIES COMMISSION HAS APPROVED OR
DISAPPROVED THESE SECURITIES OR PASSED UPON THE ADEQUACY OR ACCURACY OF THIS
PROSPECTUS. ANY REPRESENTATION TO THE CONTRARY IS A CRIMINAL OFFENSE.
THE DATE OF THIS PROSPECTUS IS MARCH , 2001
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TABLE OF CONTENTS
PAGE
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PROSPECTUS SUMMARY.......................................... 1
RISK FACTORS................................................ 13
USE OF PROCEEDS............................................. 19
CAPITALIZATION.............................................. 19
SELECTED FINANCIAL DATA OF THE COMPANY...................... 19
MANAGEMENT.................................................. 20
PUBLIC SERVICE ELECTRIC, EL PASO AND SUMMARIZED FINANCIAL
INFORMATION OF PUBLIC SERVICE ELECTRIC AND EL PASO........ 24
EL PASO MERCHANT............................................ 30
LIMESTONE................................................... 31
MESQUITE AND CHAPARRAL...................................... 31
CHAPARRAL MANAGEMENT........................................ 31
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS................................. 32
FORWARD-LOOKING STATEMENTS.................................. 36
REGULATION OF THE ELECTRIC INDUSTRY......................... 37
THE ENERGY SALES TRANSACTIONS............................... 40
SECURITY OWNERSHIP OF OUR OWNERS............................ 43
SUMMARY OF OUR TRANSACTION DOCUMENTS........................ 44
AMENDED POWER PURCHASE AGREEMENT............................ 44
POWER SERVICES AGREEMENT.................................... 50
ADMINISTRATIVE SERVICES AGREEMENT........................... 57
EL PASO PERFORMANCE GUARANTY................................ 59
RELATIONSHIPS WITH AFFILIATES AND RELATED TRANSACTIONS...... 61
THE EXCHANGE OFFER.......................................... 61
DESCRIPTION OF THE BONDS.................................... 70
DESCRIPTION OF OUR PRINCIPAL FINANCING DOCUMENTS............ 87
U.S. FEDERAL INCOME TAX CONSEQUENCES........................ 88
ERISA CONSIDERATIONS........................................ 92
PLAN OF DISTRIBUTION........................................ 94
LEGAL MATTERS............................................... 95
EXPERTS..................................................... 95
AVAILABLE INFORMATION....................................... 95
INDEX TO FINANCIAL STATEMENTS............................... F-1
ANNEX A -- POWER SERVICES AGREEMENT ASSESSMENT.............. A-1
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You may not transfer or resell the Series B bonds except as permitted under
the Securities Act of 1933 and applicable state securities laws.
You should rely only on the information contained in this document or any
supplement. We have not authorized anyone to provide you with any information
that is different. If you receive any unauthorized information, you must not
rely on it. You should disregard anything we said in an earlier document that is
inconsistent with what is in our prospectus.
You should not assume that the information in this prospectus or any
supplement or any of the information incorporated by reference in this
prospectus or any supplement is current as of any date other than the date on
the front page of this prospectus.
This document is not an offer to sell nor is it seeking an offer to buy
these securities in any state or jurisdiction where the offer or sale is not
permitted.
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PROSPECTUS SUMMARY
In this prospectus, the words "Company," "we," "our," "ours" and "us' refer
only to Cedar Brakes I, L.L.C. and not to any of our parent or sister companies
or to anybody else. The following summary contains basic information about us
and the exchange offer. It does not contain all of the information that is
important to you. For a more complete understanding of our business and
financial status and the Series B bonds that we are offering, you should read
carefully this entire prospectus and other documents that we will refer you to.
The term "El Paso" refers to El Paso Corporation (formerly known as El Paso
Energy Corporation). For a discussion of factors to be considered in connection
with an investment in the bonds, see "Risk Factors." For the definitions of some
of the terms used throughout this prospectus, see "Description of the
Bonds -- Defined Terms."
THE EXCHANGE OFFER
On September 26, 2000, we completed the private offering of $310,600,000 of
the Series A bonds. We entered into a registration rights agreement with the
initial purchasers in the private offering of the Series A bonds in which we
agreed, among other things, to deliver to you this prospectus and to complete
this exchange offer within 270 days of the original issuance of the Series A
bonds. You are entitled to exchange in this exchange offer Series A bonds that
you hold for registered Series B bonds with substantially identical terms. You
should read the discussion under the headings "Summary of the Terms of the
Series B Bonds" beginning on page 5 and "Description of the Bonds" beginning on
page 69 for further information regarding the Series B bonds.
We believe that the Series B bonds that will be issued in this exchange
offer may be resold by you without compliance with the registration and
prospectus delivery provisions of the Securities Act. You should read the
discussion under the headings "Summary of the Terms of the Exchange Offer"
beginning on page 3 and "The Exchange Offer" beginning on page 60 for further
information regarding this exchange offer and resale of the Series B bonds.
OUR COMPANY AND BUSINESS
We were formed as a Delaware limited liability company on March 3, 2000
solely to:
- acquire the right, title and interest to a long-term power purchase
agreement;
- sell electric energy and capacity under this power purchase agreement (as
amended and restated);
- enter into other related agreements, the indenture and the related
financing documents and undertake the transactions contemplated
thereunder;
- engage in other activities that are related to or incidental to the
foregoing; and
- issue the bonds.
Our sole business is the wholesale sale of electric capacity and electric
energy to Public Service Electric & Gas Company, a New Jersey corporation, under
a long-term power purchase agreement. This power purchase agreement was entered
into on June 15, 1988, between Public Service Electric and Newark Bay
Cogeneration Partnership L.P., a New Jersey limited partnership and is referred
to in this prospectus as the original power purchase agreement. In March 2000,
we and Public Service Electric agreed to amend the original power purchase
agreement effective upon the transfer of the original power purchase agreement
to us. Upon the consummation of the offering of the Series A bonds, we used the
proceeds of the offering of the Series A bonds to pay Newark Bay the purchase
price for the original power purchase agreement, the original power purchase
agreement was transferred to us and the amendment of its terms became effective.
The amended original power purchase agreement was then restated in its entirety.
In this prospectus, we refer to the original power purchase agreement after its
amendment and restatement as the amended power purchase agreement.
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We are classified as a public utility subject to regulation by the Federal
Energy Regulatory Commission under the Federal Power Act. We have no employees.
Our material assets are comprised of the amended power purchase agreement,
receivables that are generated or accrue under the amended power purchase
agreement, the proceeds of such receivables, our interest in the amounts held in
our accounts described in this prospectus and the following additional
contracts, which, together with the amended power purchase Agreement, we refer
to as our material agreements:
- our power services agreement dated September 20, 2000, with El Paso
Merchant Energy L.P., an indirect wholly owned subsidiary of El Paso;
- our administrative services agreement dated September 20, 2000, with El
Paso Merchant;
- the guaranty dated September 20, 2000 by El Paso of El Paso Merchant's
performance under the power services agreement and the administrative
services agreement;
- a consent and agreement with Public Service Electric and the trustee;
- a consent and agreement with El Paso Merchant and the trustee; and
- a consent and agreement with El Paso and the trustee.
For more information about our material agreements, see "Summary of Our
Transaction Documents" below.
Our company is owned directly 100% by Mesquite Investors, L.L.C. Mesquite
is owned indirectly by El Paso and Limestone Electron Trust. A wholly-owned
subsidiary of El Paso, El Paso Chaparral Management, L.P., manages the
operations of Mesquite. See "-- Chaparral Management." Our day-to-day operations
are managed by officers and employees of El Paso Merchant under the
administrative services agreement with us. Our principal executive offices are
located at 1001 Louisiana Street, Houston, Texas 77002. Our telephone number is
(713) 420-2131.
For a more detailed description of our organization and ownership
structure, please see "Management" and the chart on page 20.
RATIO OF EARNINGS TO FIXED CHARGES
For the period from March 3, 2000 to December 31, 2000, our earnings were
inadequate to cover fixed charges by $3,132,000. Because we were organized on
March 3, 2000, we cannot calculate a ratio of earnings to fixed charges for any
prior periods. For the purposes of calculating the ratio of earnings available
to cover fixed charges:
- earnings consist of income from continuing operations and fixed charges,
and
- fixed charges consist of interest on borrowings (whether expensed or
capitalized) and related amortization.
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SUMMARY OF THE TERMS OF THE EXCHANGE OFFER
The Exchange Offer......... We are offering to exchange up to $310,600,000
principal amount of the Series B bonds for up to
$310,600,000 principal amount of the Series A
bonds. As of the date of this prospectus, Series A
bonds representing $310,600,000 aggregate principal
amount are outstanding. The Series B bonds will
evidence the same debt as the Series A bonds, and
the Series A bonds and the Series B bonds will be
governed by the same indenture.
The Series B bonds are described in detail under
the heading "Description of the Bonds" beginning on
page 69 of this prospectus.
Resale..................... We believe that you will be able to freely transfer
the Series B bonds without registration or any
prospectus delivery requirement; however, some
broker-dealers and some of our affiliates may be
required to deliver copies of this prospectus if
they resell any Series B bonds.
Expiration Date............ The exchange offer will expire at 5:00 p.m., New
York City time, [ ], 2001 or a later date and
time if we extend it.
Withdrawal................. You may withdraw the tender of any Series A bonds
pursuant to the exchange offer at any time prior to
the expiration date. We will return, as promptly as
practicable after the expiration or termination of
the exchange offer, any Series A bonds not accepted
for exchange for any reason without expense to you.
Interest on the Series B
Bonds and the Series A
Bonds.................... Interest on the Series B bonds will accrue from the
date of the original issuance of the Series A bonds
or from the date of the last payment of interest on
the Series A bonds, whichever is later. No
additional interest will be paid on Series A bonds
tendered and accepted for exchange.
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. See "The Exchange Offer -- Conditions of
the Exchange Offer" beginning on page 66 of this
prospectus.
Procedures for Tendering
Series A Bonds........... If you wish to accept the exchange offer, you must
complete, sign and date the accompanying letter of
transmittal in accordance with the instructions in
the letter of transmittal, and deliver the letter
of transmittal, along with the Series A bonds and
any other required documentation, to the exchange
agent. By executing the letter of transmittal, you
will represent to us that, among other things:
- any Series B bonds you receive will be acquired
in the ordinary course of business,
- you are not participating, and you have no
arrangement or understanding with any person to
participate, in the distribution of the Series B
bonds, and
- you are not an affiliate of ours or a
broker-dealer tendering Series A bonds acquired
directly from us.
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If you are not a broker-dealer, you will also be
representing that you are not engaged in and do not
intend to engage in a distribution of the Series B
bonds.
Each broker-dealer issuing Series B bonds for its
own account in exchange for Series A bonds must
acknowledge that it will deliver a prospectus
meeting the requirements of the Securities Act in
connection with any resale of the Series B bonds.
The letter of transmittal states that, by making
this acknowledgement 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. A broker-dealer who
acquired the Series A bonds for its own account as
a result of market-making or other trading
activities may use this prospectus for an offer to
resell, resale or other transfer of the Series B
bonds.
If you hold your Series A bonds through The
Depository Trust Company and wish to participate in
the exchange offer, you may do so through the
Depository Trust's Automated Tender Offer Program.
By participating in the exchange offer, you will
agree to be bound by the letter of transmittal as
though you had executed such letter of transmittal.
We will accept for exchange any and all Series A
bonds which are properly tendered (and not
withdrawn) in the exchange offer prior to the
expiration date. The Series B bonds issued pursuant
to the exchange offer will be delivered promptly
following the expiration date. See "The Exchange
Offer -- Acceptance of Series A Bonds for Exchange"
beginning on page 62 of this prospectus.
Effect of Not Tendering.... Series A bonds 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. We will have no further obligation to
provide for the registration under the Securities
Act of such Series A bonds.
Special Procedures for
Beneficial Owners.......... If you are a beneficial owner whose Series A bonds
are registered in the name of a broker, dealer,
commercial bank, trust company or other nominee and
wish to tender such Series A bonds 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 Series A bonds, you may,
in some instances, do so according to the
guaranteed delivery procedures set forth elsewhere
in this prospectus under "The Exchange
Offer -- Procedures for Tendering Series A
Bonds -- Guaranteed Delivery" beginning on page 65
of this prospectus.
Registration Rights
Agreement.................. We sold the Series A bonds on September 26, 2000,
to the initial purchaser in a transaction that was
exempt from the SEC's registration requirements. In
connection with the sale, we entered into a
registration rights agreement with the initial
purchaser which grants the holders of the Series A
bonds specified exchange and registration
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rights. This exchange offer satisfies those rights,
which terminate upon consummation of the exchange
offer. You will not be entitled to any exchange or
registration rights with respect to the Series B
bonds.
U.S. Federal Income Tax
Considerations........... We believe the exchange of Series A bonds for
Series B bonds pursuant to the exchange offer will
not constitute a sale or an exchange for federal
income tax purposes. See "U.S. Federal Income Tax
Consequences" beginning on page 87 of this
prospectus.
Use of Proceeds............ We will not receive any proceeds from the exchange
of bonds pursuant to the exchange offer.
Exchange Agent............. We have appointed Bankers Trust Company as the
exchange agent for the exchange offer. The mailing
address and telephone number of the exchange agent
are BT Services Tennessee, Inc., Reorganization
Unit, P.O. Box 292737, Nashville, Tennessee
37229-2737. See "The Exchange Offer -- Exchange
Agent" beginning on page 68 of this prospectus.
SUMMARY OF THE TERMS OF THE SERIES B BONDS
The form and term of the Series B bonds are substantially the same as the
form and terms of the Series A bonds, except that the Series B bonds are
registered under the Securities Act. As a result, the Series B bonds will not
bear legends restricting their transfer and will not contain the registration
rights contained in the Series A bonds.
Issuer..................... Cedar Brakes I, L.L.C., a Delaware limited
liability company.
Bonds Offered.............. $310,600,000 aggregate principal amount of 8 1/2%
Series B Senior Secured Bonds due February 15,
2014. The bonds are senior to, and rank first in
priority with respect to, all our current and
future indebtedness.
Maturity Date.............. February 15, 2014.
Interest Payment Dates..... The fifteenth calendar day of each February and
August (or if that day is not a business day, then
the next succeeding business day), commencing on
February 15, 2001. A business day is a day on which
banks are not required or authorized to close in
the City of New York.
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Principal Payment Dates and
Amortization............. We are required to pay principal on the bonds
annually on the fifteenth calendar day of each
February (or if that day is not a business day,
then the next succeeding business day), commencing
on February 15, 2002:
PERCENTAGE OF PRINCIPAL
PRINCIPAL PAYMENT DATE AMOUNT PAYABLE
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February 15, 2002 1.9
February 15, 2003 2.5
February 15, 2004 3.5
February 15, 2005 4.9
February 15, 2006 5.8
February 15, 2007 6.7
February 15, 2008 7.7
February 15, 2009 8.8
February 15, 2010 9.9
February 15, 2011 11.3
February 15, 2012 12.6
February 15, 2013 14.3
February 15, 2014 10.1
Ratings.................... Baa2 by Moody's, BBB by Standard & Poor's and BBB
by Fitch.
Limited Recourse
Obligations................ The obligations to pay principal of, interest and
Make-Whole Premium, if any, on the bonds will be
solely our obligations. You will not have any other
recourse against our affiliates or any
incorporator, stockholder, member, officer,
employee or director of ours or any such affiliate
for any failure by us to satisfy obligations under
the bonds.
Collateral................. We granted to the trustee at the closing date of
the offering of the Series A bonds, on behalf of
and for the benefit of the holders of bonds, all of
our right, title and interest in all of our assets,
namely:
- our material agreements;
- our collections and all amounts payable to us
arising out of, attributable to, in respect of or
otherwise in connection with our collections;
- all other amounts payable to us pursuant to our
material agreements;
- the accounts and all funds and all investments
and proceeds on deposit therein from time to
time;
- all damages and other amounts payable to us in
respect of the foregoing;
- all of our rights, claims, powers, privileges and
remedies with respect to the foregoing; and
- all present and future claims and demands in
respect of any or all of the foregoing.
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In this prospectus, "collections" means all amounts
payable to us from Public Service Electric pursuant
to the amended power purchase agreement and amounts
payable by:
- El Paso Merchant pursuant to Article V(F) of the
power services agreement to cover any shortfall
payments;
- El Paso Merchant pursuant to Article IV(B) and
Article V(E) of the power services agreement to
cover any excess amounts;
- El Paso pursuant to the El Paso performance
guaranty to cover any shortfall payments and
excess amounts of El Paso Merchant under Article
IV(B) and Article V(E) of the power services
agreement; and
- all earnings on permitted investments from
amounts in the collections account and the
liquidity account.
Redemption at Our Option... We may choose to redeem the bonds, in whole or in
part, at any time, at our option on not less than
30 nor more than 60 days notice to the bond holders
at a redemption price equal to the outstanding
principal amount of the bonds to be redeemed, plus
accrued interest on these bonds to the date of the
redemption, plus a Make-Whole Premium, if any. The
Make-Whole Premium is based on the rates of
treasury securities with average lives comparable
to the remaining average lives of the applicable
bonds, plus 50 basis points.
Accounts................... Pursuant to the indenture, the trustee established
the following accounts: (1) the collections
account, (2) the liquidity account and (3) the
damages and indemnity account. See "Description of
the Bonds -- The Accounts -- Establishment of
Accounts."
Collections Account........ All collections and all transfer payments from the
liquidity account will be deposited into the
collections account. An amount equal to $2,396,509
from the proceeds of the offering of the Series A
bonds was deposited into the collections account.
Amounts on deposit in the collections account must
be used to make payments in accordance with the
priorities set forth in "-- Withdrawals from the
Collections Account" below.
Liquidity Account.......... On the closing date of the offering of the Series A
bonds, we deposited into the liquidity account
$13,200,500, an amount equal to the liquidity
reserve required balance. This amount was part of
the proceeds from the Series A bonds offering. In
the event sufficient funds are not available in the
collections account to pay the principal or
interest on the bonds, amounts in the liquidity
account will be transferred into the collections
account and used by the trustee to pay this
shortfall. Amounts withdrawn from the liquidity
account will be replenished from the collections
account in accordance with the priority set forth
in "-- Withdrawals from the Collections Account"
below. El Paso may withdraw the cash on deposit in
the liquidity account by replacing the cash
withdrawn with one or more letters of credit or a
guaranty from El Paso, in the amount of the cash
withdrawn. Amounts in excess of the liquidity
reserve required balance on deposit in the
liquidity account on any interest payment date will
be transferred on the next principal payment date
(but no earlier than February 15, 2003) to the
collections account.
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Damages and Indemnity
Account.................... All payments to be made by El Paso Merchant
pursuant to the power services agreement and by El
Paso pursuant to the El Paso performance guaranty
to cover:
- damages payable by us to Public Service Electric
as a result of our default under the amended
power purchase agreement;
- indemnity payments payable by us to Public
Service Electric on account of third-party
liability claims under the amended power purchase
agreement; and
- distribution surcharges payable by us to Public
Service Electric on account of the fact that
these distribution charges were not paid to
Public Service Electric because of a statutory
exemption under New Jersey law.
Amounts must be drawn from the damages and
indemnity account to pay such damages, indemnity
payments and distribution surcharges.
Withdrawals from the
Collections Account........ The trustee must apply amounts in the collections
account as follows, and in the following order of
priority:
- monthly, to transfer to the trustee the amount of
the trustee's monthly fees;
- monthly, to pay El Paso Merchant for the capacity
and energy that El Paso Merchant sold to us under
the power services agreement;
- semi-annually, to the payment of interest due on
the bonds;
- annually, to the payment of principal and
Make-Whole Premium (if any) due on the bonds;
- semi-annually, to replenish any amounts drawn
from the liquidity account so as to maintain the
liquidity account required balance;
- semi-annually, to El Paso Merchant an amount
equal to the accrued and unpaid fees and expenses
owed El Paso Merchant under the administrative
services agreement; and
- annually, to us for distribution to our members;
provided that (a) no event of default (or other
event which would with notice or lapse of time or
both become an event of default) has occurred and
is continuing and (b) the Debt Service Coverage
Ratio for the preceding six-month period is equal
to or exceeds 1.03 to 1.00.
Principal Covenants........ The indenture contains a number of covenants on our
part, among them:
- restrictions on the incurrence of additional
indebtedness;
- limitations on liens and encumbrances, except to
the extent the failure to comply could not
reasonably be expected to result in a material
adverse effect;
- restrictions on the payments of distributions to
our members or any owner of a beneficial interest
in us;
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- limitations on the sale or transfer of the
collateral, mergers, changes in legal form or
other fundamental changes;
- a prohibition on undertaking obligations with
respect to any guaranty;
- limitations on transactions entered into with
affiliates;
- limitations on investments in other persons;
- an obligation to maintain our existence;
- an obligation to comply with laws;
- restrictions on our use of the proceeds from the
issuance of the bonds;
- limitations on the assignment of our rights and
obligations under any of our material agreements,
amendment of our material agreements and our
entering into additional contracts; and
- an obligation to schedule and deliver the annual
energy deliveries.
See "Description of the Bonds -- Covenants."
Events of Default and
Remedies................... An event of default will occur under the indenture
if, among other things,
- we fail to pay any principal of or Make-Whole
Premium, if any, on the bonds when due and
payable and this default continues for a period
of five days or more;
- we fail to pay any interest or any other amount
required to be paid with respect to the bonds and
this default continues for a period of 15 days or
more;
- we, El Paso or Public Service Electric fail to
perform any material term, covenant or obligation
contained in any of our material agreements or
any financing document, unless in each case
failure to perform could not reasonably be
expected to result in a material adverse effect,
and such failure continues for 30 days or more
after we are provided notice of such failure;
- any of our material agreements or financing
documents becomes or is found to be unenforceable
or illegal, and that event could reasonably be
expected to result in a material adverse effect;
- (1) the liens on any material portion of the
collateral cease to be valid and perfected first
priority security interests or (2) any other of
our creditors asserts any rights or interest with
respect to the collateral, or our right to
receive payments with respect to the collateral
is otherwise terminated or impaired and the
assertion of rights or interests or the
termination or impairment of our right to receive
payments could reasonably be expected to result
in a material adverse effect;
- events occur related to our insolvency, such as
the commencement of a liquidation or dissolution
proceeding unstayed for 60 days or the
application by us of a voluntary bankruptcy
proceeding;
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- it becomes unlawful for us to perform any of our
obligations under the indenture or the bonds, or
any of our obligations under the indenture or the
bonds ceases to be valid, binding or enforceable,
unless such event or occurrence could not
reasonably be expected to result in a material
adverse effect;
- any of the amended power purchase agreement or
the El Paso performance guaranty terminates
before the end of its term;
- one or more judgments or decrees are entered
against us in excess of $15 million in the
aggregate which have not been vacated,
discharged, stayed or bonded pending appeal
within 60 days from the entry thereof; or
- we fail to observe or perform specified covenants
in the registration rights agreement with the
initial purchaser, and such failure continues for
a period of 30 days after notice is given to us.
If an event of default (other than an event of
default caused by our bankruptcy) occurs and is
continuing, then the trustee, upon the direction of
no less than 25% (for an event of default with
respect to failure to make payments on the bonds)
or the holders of not less than 51% in aggregate
principal amount of the outstanding bonds (for any
other event of default), must declare the principal
amount of all the bonds to be due and payable
immediately, and upon any such declaration the
principal amount, any accrued and unpaid interest,
any Make-Whole Premium and all other amounts
payable under the bonds will become immediately due
and payable. If a bankruptcy event of default
occurs, the principal amount of, any accrued
interest on, any Make-Whole Premium and all other
amounts payable under the bonds will automatically
become immediately due and payable. See
"Description of the Bonds -- Remedies."
Indenture Trustee.......... Bankers Trust Company.
Paying Agent, Registrar and
Transfer Agent........... Bankers Trust Company serves as the paying agent,
security registrar and transfer agent for the
bonds.
Governing Law and
Jurisdiction............... The bonds, the indenture and the other financing
documents are governed by the laws of the State of
New York.
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SUMMARY OVERVIEW OF OUR ENERGY SALES TRANSACTIONS
The following chart depicts some of our material agreements, the
transaction structure of our energy sales and the relationship to payments on
the bonds:
#GRAPHIC DEPICTION OF THE TRANSACTION#
THE TRANSACTIONS
We purchased the original power purchase agreement from Newark Bay pursuant
to a purchase and sale agreement. We expect that interest and principal on the
bonds will be paid solely from capacity and energy payments from Public Service
Electric to us under the amended power purchase agreement (as supplemented, if
revenues from these capacity and energy payments are not available, by funds in
the liquidity account). All scheduled payments of principal and interest on the
bonds have been calculated so as to be paid from the total amount of the
payments that we expect to receive each year from Public Service Electric. We
have entered into the power services agreement and the administrative services
agreement with El Paso Merchant in order to have El Paso Merchant perform all of
our obligations and exercise all of our rights under all of our material
agreements and the indenture and the related financing documents under which the
Series A bonds were issued and the Series B bonds will be issued. See
"Management's Discussion and Analysis of Financial Condition and Results of
Operations; "The Energy Sales Transactions"; and "Summary of Our Transaction
Documents."
The energy sales transactions required approval by the Federal Energy
Regulatory Commission of the rates contained in the amended power purchase
agreement and the power services agreement and approval by the New Jersey Board
of Public Utilities of the cost recovery by Public Service Electric of the
amended power purchase agreement. In addition, the issuance of the bonds also
required the approval of the Federal Energy Regulatory Commission. All of these
approvals have been obtained and are final and non-appealable. See "Regulation."
POWER SERVICES AGREEMENT ASSESSMENT
Pace Global Energy Services LLC, an energy consulting firm that specializes
in, among other things, market forecasts in the electric power and natural gas
industries, prepared a power services agreement assessment dated September 20,
2000, included as Annex A to this prospectus. We sought this analysis by Pace to
support its decision to enter into the power services agreement with its fixed
contract rate structure and to evaluate whether the electric power capacity
resources in the Pennsylvania-New Jersey-Maryland ("PJM") power market are
sufficient to allow El Paso Merchant to perform its obligations under the power
services agreement.
Based upon Pace's analysis of the PJM power market and a review of the
relevant portions of our transaction documents, Pace believes that the contract
rates stipulated in the power services agreement reasonably reflect market
prices in the PJM market if the energy delivery flexibility that El Paso
Merchant has under the power services agreement is taken into consideration.
Specifically, the energy and capacity price contained in the power services
agreement were determined by Pace to reasonably reflect relevant
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market pricing if the flexibility embedded in the quantity and timing terms of
the agreement are valued and considered as part of that determination. This
flexibility in selecting the day peak vs. off-peak hours and season during which
El Paso Merchant can choose to sell electric power to us to meet El Paso
Merchant's obligations under the power service agreement provides option value
to El Paso Merchant. Moreover, Pace concludes that electric power capacity
resources in the PJM market are sufficient to allow El Paso Merchant to meet its
contractual obligations under the power services agreement.
Since the date of the power services agreement assessment, Pace has not
updated the natural gas prices in that assessment. Since the date on which we
entered into the amended power purchase agreement and the power services
agreement, natural gas prices have increased. Because the prices at which we buy
and sell electric power are fixed by these agreements, changes in the price of
natural gas will not affect our ability to make payments on the bonds, provided
that the other parties to these agreements fulfill their obligations.
The power services agreement assessment is meant to be read only in its
entirety and is subject to the restrictions set forth in the legal notice on its
cover page. The power services agreement assessment and the legal notice should
be read by all prospective investors in their entirety.
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RISK FACTORS
An investment in the bonds involves a significant degree of risk, including
the risks described below. You should carefully consider the following
information about these risks, together with the other information in this
prospectus, prior to exchanging your Series A bonds for the Series B bonds.
WE ARE RELYING ON PAYMENTS FROM PUBLIC SERVICE ELECTRIC UNDER THE AMENDED POWER
PURCHASE AGREEMENT FOR OUR PRIMARY SOURCE OF REVENUES.
Public Service Electric is our sole customer for purchases of electric
generating capacity and energy. Public Service Electric's payments pursuant to
the amended power purchase agreement are expected to provide 100% of our
revenues. There can be no assurance that Public Service Electric will fulfill
its payment obligations under the amended power purchase agreement. In the event
of a bankruptcy of Public Service Electric, Public Service Electric or the
bankruptcy trustee could reject its payment obligations under the amended power
purchase agreement. If Public Service Electric fails to meet its payment
obligations under the amended power purchase agreement, we will not be able to
meet our obligations to make payments of principal and interest on the bonds.
Further, under the amended power purchase agreement, Public Service Electric may
suspend its obligations to accept delivery of energy if specified events beyond
the control of Public Service Electric occur, such as a system emergency,
adverse weather conditions or labor disputes. Accordingly, we will have no
revenues for the duration of these events and there can be no assurance that we
will be able to make payments of principal and interest on the bonds during the
continuance of these events.
THE TIMING OF THE CAPACITY AND ENERGY PAYMENTS UNDER THE AMENDED POWER PURCHASE
AGREEMENT MAY AFFECT OUR ABILITY TO MAKE PAYMENTS ON THE BONDS.
With the exception of the minimum energy deliveries, we can schedule and
deliver energy at any time of the year. Accordingly, our cash flows and revenues
under the amended power purchase agreement may not be received on a regular
basis throughout the year. Interest payments on the bonds are semi-annual and
there can be no assurance that amounts received for the corresponding six-month
period pursuant to the amended power purchase agreement will be sufficient to
make the interest payments on the bonds. We have provided for the funding of a
liquidity account in an amount equal to the maximum interest due on the bonds on
any subsequent interest payment date. Amounts drawn from the liquidity account
will only be replenished out of cash otherwise available in the collections
account. There can be no assurance that amounts withdrawn from the liquidity
account can be replenished. If cash flows are not sufficient to meet our
obligations to make interest payments on the bonds and the liquidity account has
not been replenished, we will not be able to make payments of principal and
interest on the bonds.
OUR FAILURE TO PROVIDE ENERGY AND CAPACITY TO PUBLIC SERVICE ELECTRIC COULD
RESULT IN TERMINATION OF THE AMENDED POWER PURCHASE AGREEMENT PRIOR TO THE
MATURITY OF THE BONDS.
If we cause or permit to occur an event of default under the amended power
purchase agreement, Public Service Electric may have the right to terminate the
amended power purchase agreement. The amended power purchase agreement expressly
provides that with respect to defaults that are a result of our failure to
deliver energy and capacity, Public Service Electric shall be entitled to deduct
amounts (determined pursuant to a formula in the amended power purchase
agreement) from payments due to us as liquidated damages. Although the amended
power purchase agreement provides that these liquidated damages are the only
damages that Public Service Electric can claim as a result of any failure by us
to deliver energy or provide capacity, Public Service Electric could take the
position that it is entitled to other remedies provided under applicable law,
such as the right to terminate the power purchase agreement. Therefore, if one
of our defaults has occurred and is continuing, Public Service Electric could
also seek to terminate the amended power purchase agreement.
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WE ARE RELYING UPON EL PASO MERCHANT AND EL PASO TO PERFORM OUR OBLIGATIONS
UNDER OUR MATERIAL AGREEMENTS OR, UPON FAILING TO DO SO (WITHOUT EXCUSE), TO
MAKE PAYMENTS TO US.
Under the power services agreement and the administrative services
agreement, El Paso Merchant is obligated to exercise our rights and perform all
of our administrative and management obligations under our material agreements,
including exercising our right to schedule, sell and deliver the minimum energy
deliveries and the additional energy deliveries each year. If El Paso Merchant
fails to perform its obligations under the power services agreement or the
administrative services agreement, we will not be able to perform our
obligations to Public Service Electric under the amended power purchase
agreement and our obligations under our other material agreements. In that
situation, unless El Paso Merchant is excused, El Paso Merchant would be
required to make shortfall payments to us for its failure to schedule and
deliver energy. However, there can be no assurance that El Paso Merchant will be
able to make these payments.
In the event that El Paso Merchant cannot make these payments, El Paso is
required to pay these amounts pursuant to the El Paso performance guaranty.
There can be no assurance that El Paso will fulfill its obligations under the El
Paso performance guaranty. If, to the extent called upon, El Paso fails to meet
its obligations under the El Paso performance guaranty, we will not be able to
meet our obligations to make payments of interest and principal on the bonds.
Under the power services agreement, El Paso Merchant is excused from its
obligation to schedule energy deliveries if specified events beyond the control
of El Paso Merchant occur, such as adverse weather conditions or labor disputes.
In this event, neither El Paso Merchant nor El Paso will be obligated to make
shortfall payments.
IF THE POWER SERVICES AGREEMENT AND ADMINISTRATIVE SERVICES AGREEMENT TERMINATE,
THERE CAN BE NO ASSURANCE THAT WE WILL BE ABLE TO OBTAIN EQUIVALENT REPLACEMENT
SERVICES.
The power services agreement and the administrative services agreement
expressly provide that the respective agreement may be terminated prior to its
scheduled expiration date upon the occurrence of events set forth in these
agreements, such as payment default. We are a special purpose entity, and we do
not have any employees or our own source of capacity and energy. In the event of
the termination of the administrative services agreement or the power services
agreement, there can be no assurance that replacement services can be obtained
on terms as favorable as those under the current agreements. If the
administrative services agreement or the power services agreement terminates, we
may not be able to make payments of principal and interest on the bonds.
THERE WILL BE CONFLICTS OF INTEREST UNDER OUR AGREEMENTS WITH EL PASO MERCHANT
AND EL PASO.
El Paso Merchant and El Paso are affiliates of each other, and an affiliate
of each of them manages us. In negotiating the administrative services
agreement, the power services agreement and the El Paso performance guaranty, we
believe that we provided terms that are substantially similar to those that
might have been obtained from unaffiliated third parties. However, we cannot
assure you that those documents actually meet that standard.
Furthermore, in carrying out their obligations under our material
agreements to which they are parties, El Paso Merchant and El Paso may face
conflicts of interest in making decisions that affect us. In some situations, El
Paso Merchant may be required under the administrative services agreement to
enforce our rights against itself under the power services agreement or against
its ultimate parent, El Paso, under the El Paso performance guaranty. For
example, under the administrative services agreement, El Paso Merchant is
required to exercise our rights under the power services agreement, which
includes enforcing our right to receive payments, such as shortfall payments and
other damages, from El Paso Merchant. Although El Paso Merchant and El Paso have
agreed to carry out their obligations to us in a manner that is
nondiscriminatory to us, as a practical matter our ability to monitor compliance
is limited. As a result, we cannot guarantee that El Paso Merchant and El Paso
will carry out their obligations to us in a manner that is nondiscriminatory to
us. If they do not, we may not be able to fulfill our obligations under the
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amended power purchase agreement and Public Service Electric may have the right
to terminate the amended power purchase agreement. In the event that Public
Service Electric terminates the amended power purchase agreement due to our
inability to fulfill our obligations under that agreement, we will not be able
to make payments of principal and interest on the bonds.
WE ARE THE ONLY PARTY REQUIRED TO MAKE PAYMENTS ON THE BONDS, AND, IF WE DEFAULT
ON THE BONDS, YOUR RECOURSE AND YOUR ABILITY TO ACT MAY BE LIMITED.
We are the only party required to make payments on the bonds. We conduct no
other business and have no other significant assets other than our rights under
our material agreements and the issuing of the bonds. We have no operating
history and no experience in the purchase or sale of energy. No entity,
including Public Service Electric, El Paso Merchant or El Paso, and none of our
affiliates, shareholders, members, officers, directors or employees will be
required to make payments on the bonds or will in any way guarantee the payment
on the bonds.
A number of actions to enforce the rights of the holders, such as
acceleration of the principal, interest and Make-Whole Premium on the bonds, may
be taken by the trustee only with the approval of holders of 25% of the
outstanding principal amount of the bonds. A majority of that outstanding
principal amount of the bonds must approve the trustees' actions to enforce the
rights of the holders in the event of all other defaults (other than bankruptcy
events). These requirements of holder approval may limit the ability of the
trustee to exercise specific remedies or prolong the time required for the
trustee to act. See "Description of the Bonds -- Remedies."
OUR BUSINESS IS SUBJECT TO SUBSTANTIAL REGULATIONS AND PERMITTING REQUIREMENTS
AND MAY BE ADVERSELY AFFECTED BY OUR INABILITY TO COMPLY WITH EXISTING
REGULATIONS OR REQUIREMENTS OR CHANGES IN APPLICABLE REGULATIONS OR
REQUIREMENTS.
Our business, as well as those of El Paso Merchant, Public Service Electric
and El Paso, is subject to extensive energy regulation by federal, state and
local authorities. These regulations impose numerous requirements on the
performance of our, Public Service Electric's, El Paso Merchant's and El Paso's
obligations under the amended power purchase agreement and the power services
agreement, and failure to comply with these requirements could prevent the
performance of our respective obligations under these agreements.
The Federal Energy Regulatory Commission currently considers contracts for
the wholesale sale of electric power to be subject to its jurisdiction.
Consequently, any proposed transfer of either or both the amended power purchase
agreement and the power services agreement, including a transfer to the trustee
upon foreclosure, is subject to Federal Energy Regulatory Commission approval,
and any modification of the amended power purchase agreement and the power
services agreement may require Federal Energy Regulatory Commission approval as
well. The Federal Energy Regulatory Commission has pre-approved all of our
currently contemplated future security issuances and assumptions of liability
(including the issuance of the bonds offered hereby). Any further security
issuances and assumptions of liability by us would require pre-approval by the
Federal Energy Regulatory Commission in the event that our power marketing
authorization from the Federal Energy Regulatory Commission is revoked.
The negotiated rates contained in the amended power purchase agreement and
the power services agreement require approval by the Federal Energy Regulatory
Commission. Although the Federal Energy Regulatory Commission has approved the
rates to be charged in the amended power purchase agreement and the power
services agreement, the Federal Energy Regulatory Commission has continuing
jurisdiction over those rates. The Federal Energy Regulatory Commission would
have to meet a high burden in order to modify the rates, and, as a matter of
practice and policy, the Federal Energy Regulatory Commission has steadfastly
refused to modify rates after initial approval. There can be no assurance,
however, that the Federal Energy Regulatory Commission will permit those rates
to remain in place for the term of the amended power purchase agreement and the
power services agreement, and, in such event, the rates that
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we are permitted to charge could be lower, resulting in less cash available for
us to make debt service payments on the bonds.
Marketing power at market-based or negotiated rates requires a power
marketing authorization issued by the Federal Energy Regulatory Commission based
on several criteria, including a showing that the applicant lacks market power
and that there is no opportunity for abusive transactions involving regulated
affiliates of the marketer. Although El Paso Merchant has received these power
marketing authorizations from the Federal Energy Regulatory Commission, these
authorizations could be revoked if El Paso Merchant fails in the future to
satisfy the applicable criteria or if the Federal Energy Regulatory Commission
changes its rate-making policies.
We cannot assure you that the existing laws and regulations will not be
revised or reinterpreted, that new laws and regulations will not be adopted or
become applicable to us or the parties on whom we are relying in this
transaction or that future changes in laws and regulations will not have a
detrimental effect on our business. In addition, the structure of federal and
state energy regulation is currently, and may continue to be, subject to
challenges and restructuring proposals. Although not currently required,
additional regulatory approvals may be required in the future due to a change in
laws and regulations or for other reasons. We cannot assure you that we, Public
Service Electric, El Paso Merchant or El Paso will be able to obtain all
required regulatory approvals that may be required in the future, or any
necessary modifications to existing regulatory approvals, or maintain all
required regulatory approvals. Such modifications could result in the loss of
our status as a power marketer and our ability to sell the capacity and energy
to Public Service Electric at the negotiated rates set forth in the amended
power purchase agreement. In this event we could be required to sell to Public
Service Electric at lower rates.
If there is a change in regulations, or a delay in obtaining any regulatory
approvals or we, Public Service Electric, El Paso Merchant or El Paso fail to
obtain or comply with any required regulatory approvals, then we may not be able
to comply with our obligations under our material agreements and we will be
unable to meet our obligations to make payments of principal and interest on the
bonds.
OUR ABILITY TO MAKE PAYMENT ON THE BONDS MAY BE AFFECTED IN A BANKRUPTCY OF THE
COUNTERPARTIES TO OUR MATERIAL AGREEMENTS BY THE FACT THAT THESE AGREEMENTS ARE
EXECUTORY.
The amended power purchase agreement, power services agreement,
administrative services agreement or the El Paso performance guaranty may be
treated as executory contracts by any bankruptcy court having jurisdiction over
them. As a result, in the event of the bankruptcy of Public Service Electric, El
Paso Merchant or El Paso, the bankrupt party or the bankruptcy trustee could
reject any or all of the amended power purchase agreement, power services
agreement, administrative services agreement or the El Paso performance
guaranty, as the case may be, if they are found to be executory contracts.
Rejection of a contract is treated as a breach of the contract and would result
in our having an unsecured claim against the estate of the debtor for damages as
a result of the breach.
IN THE EVENT OF OUR OWN BANKRUPTCY, THE ABILITY OF THE HOLDERS OF THE BONDS TO
FORECLOSE WILL BE AFFECTED BY THE AUTOMATIC STAY IN BANKRUPTCY.
In the event of our bankruptcy, the holders would have a secured claim
against us for the amounts due under the bonds. The holders' claim would be
secured by their interest in the collateral. Absent relief granted by the
bankruptcy judge from the automatic stay in bankruptcy, however, the holders
could not foreclose on any of the collateral and there may not be sufficient
funds to pay amounts due in respect of the bonds.
IT MAY BE DIFFICULT TO REALIZE THE VALUE OF THE COLLATERAL PLEDGED TO SECURE THE
BONDS.
Our obligation to make payments on the bonds is secured only by the
collateral described in this prospectus. The trustee's ability to foreclose on
the collateral on your behalf may be subject to perfection, the consent of third
parties such as Public Service Electric and El Paso Merchant, priority issues
and practical problems associated with the realization of the trustee's security
interest in the collateral. In
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addition, pursuant to the consent and agreement with Public Service Electric, in
the event that the trustee or any designee and assignee succeeds to our
interests under the amended power purchase agreement, this successor will assume
liability for our obligations under the amended power purchase agreement,
including those obligations arising prior to such succession. We cannot assure
you that foreclosure on the collateral will be sufficient to make all payments
on the bonds.
THERE IS NO EXISTING MARKET FOR THE BONDS AND WE CANNOT ASSURE YOU THAT AN
ACTIVE TRADING MARKET WILL DEVELOP FOR THE BONDS.
We have been informed by the initial purchaser of the Series A bonds that
it intends to make a market in the bonds after the completion of this offering.
However, the initial purchaser is not required to make a market in the bonds,
and it may cease market-making at any time without notice. We cannot assure you
that an active market for the bonds will develop. Moreover, even if a market for
the bonds does develop, the bonds could trade at a discount from their face
amount. If a market for the bonds does not develop, you may be unable to resell
the bonds for an extended period of time, if at all. Consequently, you may not
be able to liquidate your investment readily, and lenders may not readily accept
the bonds as collateral for loans.
IF YOU DO NOT PROPERLY TENDER YOUR SERIES A BONDS, YOU WILL CONTINUE TO HOLD
UNREGISTERED SERIES A BONDS AND YOUR ABILITY TO TRANSFER SERIES A BONDS WILL BE
ADVERSELY AFFECTED.
We will only issue Series B bonds in exchange for Series A bonds that are
timely received by the exchange agent together with all required documents,
including a properly completed and signed letter of transmittal. Therefore, you
should allow sufficient time to ensure timely delivery of the Series A bonds and
you should carefully follow the instructions on how to tender your Series A
bonds. Neither we nor the exchange agent are required to tell you of any defects
or irregularities with respect to your tender of the Series A bonds. If you do
not tender your Series A bonds or if we do not accept your Series A bonds
because you did not tender your Series A bonds properly, then, after we
consummate the exchange offer, you may continue to hold Series A bonds that are
subject to the existing transfer restrictions. After the exchange offer is
consummated, if you continue to hold any Series A bonds, you may have difficulty
selling them because there will be fewer Series A bonds outstanding.
THE MARKET VALUE OF THE SERIES B BONDS COULD BE MATERIALLY ADVERSELY AFFECTED IF
ONLY A LIMITED NUMBER OF SERIES B BONDS ARE AVAILABLE FOR TRADING.
To the extent that a large amount of the Series A bonds are not tendered or
are tendered and not accepted in the exchange offer, the trading market for the
Series B bonds could be materially adversely affected. Generally, a limited
amount, or "float," of a security could result in less demand to purchase such
security and, as a result, could result in lower prices for such security. We
cannot assure you that a sufficient number of Series A bonds will be exchanged
for Series B bonds so that this does not occur.
OUR REVENUE PROJECTIONS ASSUME THAT CAPACITY RESOURCES WITHIN THE PJM MARKET ARE
SUFFICIENT TO ENSURE THAT EL PASO MERCHANT CAN MEET ITS CONTRACTUAL OBLIGATIONS
UNDER THE POWER SERVICES AGREEMENT.
Based upon the Power Services Agreement Assessment, we have assumed that El
Paso Merchant will be able to perform its capacity and energy obligations under
the power services agreement. According to the Power Services Agreement
Assessment, there may be times when the PJM electric transmission system may
experience disruptions due to system component failures or act-of-god events. As
a result of the occurrence of such events, El Paso Merchant may not be able to
meets its obligations, and we, in turn, may not be able to sell a sufficient
amount of energy to Public Service Electric under the amended power purchase
agreement. While we have provided for shortfall payments from El Paso Merchant,
El Paso Merchant may be excused from making these payments as a result of force
majeure. If this occurs, we will not be able to make payments of principal and
interest on the bonds.
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HOLDERS OF BENEFICIAL INTERESTS IN GLOBAL BONDS MAY BE UNABLE TO TRANSFER OR
PLEDGE SUCH INTERESTS IF PHYSICAL DELIVERY IS REQUIRED BY APPLICABLE LAW.
Holders may take their interests in the bonds through owning beneficial
interests in global bonds. The laws of some jurisdictions may require that the
holders take physical delivery of bonds in definitive form. Accordingly, the
ability to transfer beneficial interests in a global bond to these persons may
be limited. Also, because Depositary Trust can only act on behalf of indirect
participants and specific banks, the ability of a person having a beneficial
interest in a global bond to pledge that interest to persons or entities that do
not participate in the Depositary Trust Company system, or otherwise take
actions in respect of that interest, may be affected by the lack of a physical
certificate representing that interest.
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USE OF PROCEEDS
We will not receive any cash proceeds from the issuance of the Series B
bonds. In consideration for issuing the Series B bonds as contemplated in this
prospectus, we will receive, in exchange, Series A bonds in like principal
amount, which will be canceled, and as such will not result in any increase in
our indebtedness.
Our net proceeds from the offering of the Series A notes were approximately
$307,882,250. We used the net proceeds as follows:
(1) to pay the purchase price of $289,830,150 for the original power
purchase agreement;
(2) to fund the liquidity account in an amount equal to $13,200,500;
(3) to fund the collections account in an amount equal to $2,396,509;
and
(4) to pay costs, fees and expenses incurred in connection with the
transactions contemplated by the indenture.
CAPITALIZATION
The capitalization of our company as of December 31, 2000 consisted of ten
membership interests which had a deficit balance of approximately $3.1 million
and long-term indebtedness of approximately $311 million.
SELECTED FINANCIAL DATA OF THE COMPANY
Set forth below is summary financial data of our company as of December 31,
2000 and for the period from March 3, 2000 to December 31, 2000. This summary
financial data has been extracted from our audited financial statements which
are included in this prospectus.
SUMMARY BALANCE SHEET DATA (in thousands):
Total assets.............................................. $ 316,118
Long-term liabilities..................................... 310,600
Member's capital.......................................... (3,131)
SUMMARY STATEMENT OF INCOME DATA (in thousands):
Operating revenues........................................ $ 14,638
Operating income.......................................... 3,909
Net loss.................................................. (3,132)
We engaged in no operations between our formation in March 2000 and
September 27, 2000.
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MANAGEMENT
We are a wholly-owned direct subsidiary of Mesquite. Mesquite is owned
indirectly by El Paso and Limestone. El Paso Chaparral Management, L.P., a
wholly-owned subsidiary of El Paso, manages the operations of Mesquite. See
"Chaparral Management." Pursuant to our limited liability company agreement, all
management powers of our company are vested in a management committee comprised
of five managers, consisting of three Class A managers and two Class B managers.
The Class A managers are designated by Mesquite. The Class B managers must be
independent and cannot be associated with any of our affiliates. A voluntary
bankruptcy petition cannot be filed by us unless the Class B managers vote to
file this bankruptcy petition. Except for bankruptcy, dissolution and similar
limited matters, the Class B managers do not exercise any power over the
management, conduct or control of the business, operations or affairs of the
company, and the vote of a majority of the Class A managers present at a meeting
constitutes the act of the management committee. Our day-to-day operations are
managed by officers and employees of El Paso Merchant under the administrative
services agreement with us. Our principal executive offices are located at 1001
Louisiana Street, Houston, Texas 77002. Our telephone number is (713) 420-2131.
The following chart sets forth a detailed description of our ownership
structure.
[DIAGRAM REFLECTING OWNERSHIP]
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The following table sets forth information relating to the business
experience of our executive officers and managers:
NAME AGE POSITION
- ---- --- --------
Clark C. Smith................ 46 President
John L. Harrison.............. 41 Vice President, Senior
Managing Director and Class A
Manager
Cecilia T. Heilmann........... 32 Vice President, Managing
Director and Controller
Timothy Sullivan.............. 38 Class A Manager
Kurt Regulski................. 42 Class A Manager
Dwight Jenkins................ 40 Class B Manager
Henry C. Mustin............... 67 Class B Manager
Clark C. Smith, our President, is also President of El Paso Merchant, which
includes the combined unregulated natural gas and power service businesses of El
Paso. Mr. Smith has over 22 years of industry experience. He has been with El
Paso Merchant since 2000. Mr. Smith was formerly President and Chief Executive
Officer of Engage Energy, Inc., a natural gas and power services venture of The
Coastal Corporation, and Westcoast Energy Inc. of Vancouver, British Columbia.
In 1988, Mr. Smith joined The Coastal Corporation as President and Chief
Executive Officer of Coastal Gas Marketing Company, and later assumed
responsibility for the formation of Coastal Gas Marketing Canada and Coastal
Electric Services Company. Mr. Smith began his business career with El Paso
Natural Gas Company in 1978, where he held various positions in regulatory
affairs, systems development and gas accounting. He joined Enron Corp. the next
year as Director of Marketing for Transwestern Pipeline Company. Later, he
became Executive Vice President of Transwestern Pipeline Company's marketing,
gas supply and state regulatory affairs. Mr. Smith earned bachelor's and
master's degrees in business administration from the University of Texas at
Austin.
John L. Harrison is our Vice President, Senior Managing Director and a
Class A Manager. He is also Senior Managing Director and Chief Financial Officer
of El Paso Merchant. Mr. Harrison has over 20 years of energy industry
experience. He joined El Paso Merchant in 1996. From 1981 until joining El Paso
Merchant, Mr. Harrison was an audit partner and held other positions in the
audit practice of Coopers & Lybrand, LLP, where he specialized in the energy
industry with an emphasis in trading and control environments. Mr. Harrison
received a bachelor's degree in business administration from Texas A&M
University and is a certified public accountant.
Cecilia T. Heilmann is our Vice President, Managing Director and
Controller. She is also Vice President, Managing Director and Controller of El
Paso Merchant. Ms. Heilmann has over eight years of industry experience. Ms.
Heilmann began her business career with El Paso in 1992, where she held various
positions in corporate accounting and strategic planning. In 1998, Ms. Heilmann
became Director of Corporate Planning for El Paso, and, in 1999, she joined El
Paso Merchant as Controller. As Controller for El Paso Merchant, she oversees
accounting, planning and credit activities. Ms. Heilmann received a bachelor's
degree in Accounting from the University of Texas at El Paso, and is a certified
public accountant.
Timothy Sullivan, a Class A Manager, is Managing Director of Restructuring
for El Paso Merchant. He has over 18 years of industry experience. Mr. Sullivan
is primarily responsible for El Paso Merchant's financial structuring and
restructuring activities throughout North America. The group he leads is
successfully acquiring and restructuring non-utility generation power projects
in the United States. Currently, this group has $900 million of project
financings either in process or closed. Mr. Sullivan joined El Paso Merchant
Energy Company in 1998. Mr. Sullivan was previously a Senior Vice President with
Citizens Power in Boston from 1995 to 1997, during which time he participated in
and led financing activities relating to project financings. During 1994, Mr.
Sullivan was a Manager for Enron Power Marketing in Houston, Texas, where he had
responsibility for the marketing of wholesale electric power in
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the northeast. Prior to joining Enron, Mr. Sullivan held various positions over
a twelve-year period with Niagara Mohawk Power Corporation in Syracuse, New
York, where he was responsible for negotiating non-utility and wholesale
electric power purchase and sale agreements. Mr. Sullivan holds a Bachelor of
Science and a Master of Business Administration degree from Syracuse University.
Kurt Regulski, a Class A Manager, is responsible for managing El Paso
Merchant's cross-commodity positions, which consist of power and gas positions
related to power plant assets. Mr. Regulski has over 20 years of experience in
the energy industry. Mr. Regulski began in the energy industry as an engineer
for Southern Natural Gas Company, where he worked in a variety of engineering
and technical support positions, including Division Manager and Manager of
Process Reengineering from 1980 to 1994. Mr. Regulski joined Sonat Marketing in
1995 as Manager, Southeast Trading, with responsibilities for managing storage,
basis and physical gas positions in the southeast U.S. He joined Sonat Power
Marketing in 1997 as Director, Power Trading, with management and trading
responsibilities for the term power trading desk. Sonat merged with El Paso in
December, 1999, and Mr. Regulski joined El Paso Merchant thereafter. Mr.
Regulski has a degree in Mechanical Engineering from Vanderbilt University.
Dwight Jenkins, a Class B Manager, is a Senior Vice President at Lord
Securities Corporation, a firm specializing in providing services to structured
finance transactions. Mr. Jenkins joined Lord in 1997. In his position with
Lord, he serves as an officer, manager, member and/or director of several
special purpose entities. He is responsible for the corporate governance and
administration of several hundred special purpose entities owned or administered
by Lord, including oversight of the administration of several hundred commercial
paper financing vehicles for utility clients. Prior to his employment with Lord,
Mr. Jenkins was a senior claims attorney at American International Group, Inc.
from 1996 to 1997 and, prior to that, he served on active duty in the U.S. Navy.
Mr. Jenkins has a Bachelor of Science degree from the U.S. Naval Academy, a
Master of Business Administration and Juris Doctor degrees from Fordham
University and is a member of the bar in New York and New Jersey.
Vice Admiral Henry C. Mustin (USN, Retired), a Class B Manager, is the
Chairman of the Board of his own consulting company, and serves as a director on
a number of boards and committees. Admiral Mustin formed his company in 1992.
From 1989 to 1992, he was the Vice President for International Marketing for the
Kaman Corporation. Admiral Mustin served as an officer in the U.S. Navy for 34
years, during which time he served variously as Deputy Chief of Naval
Operations, Senior Military Representative to the United Nations, a member of
the Joint Chiefs of Staff and a major NATO Commander. Admiral Mustin has a
Bachelor of Arts degree from the U.S. Naval Academy, a Bachelor of Science
degree in electrical engineering from the Naval Post-Graduate Academy in
Monterey, California, a Master of Science in International Affairs from the
George Washington University and is a Distinguished Graduate of the Naval War
College.
All officers have served since March 3, 2000. Our Class A Managers and Vice
Admiral Mustin have served since September 5, 2000. Mr. Jenkins has served as a
Class B Manager since January 16, 2001. Our Class A Managers serve until
resignation or the next annual meeting of members and until their respective
successors are elected and qualified. Our officers serve until removal or
resignation. Our Class B Managers serve until their successors are elected and
qualified.
Our Class A Managers and our officers are also officers of El Paso or its
affiliates. Such managers and officers may spend a substantial amount of time
managing the business and affairs of El Paso and its affiliates. Since our
day-to-day operations are managed by employees of El Paso Merchant pursuant to
the administrative services agreement, we do not expect that our managers and
officers will face a conflict regarding the allocation of their time between our
interests and the other business interests of El Paso and its affiliates.
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Our Class A Managers and officers do not receive any compensation from us.
We do not sponsor any employee benefit plans or arrangements. Our officers and
managers receive compensation from and participate in benefit plans sponsored by
El Paso and its affiliates. The Class B Managers receive a nominal annual fee
for serving on our management committee. El Paso Merchant receives a fee of
$50,000 semi-annually for the services it performs under the Administrative
Services Agreement and is entitled to reimbursement for all expenses other than
internal and overhead costs. El Paso Merchant is responsible for the
compensation of its employees, including our executive officers and Class A
Managers.
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PUBLIC SERVICE ELECTRIC, EL PASO AND SUMMARY FINANCIAL INFORMATION OF
PUBLIC SERVICE ELECTRIC AND EL PASO
Public Service Electric
Public Service Electric is an operating public utility company engaged
principally in the transmission, distribution and sale of electric energy and
gas service in the state of New Jersey.
Public Service Electric's senior secured debt is rated A3 by Moody's, A- by
Standard and Poor's, and A by Fitch.
El Paso
El Paso indirectly owns approximately 20% of the ownership interest in us,
subject to reduction upon specified events. El Paso is a global energy company
with a significant presence in the rapidly evolving wholesale energy industry.
El Paso's principal operations include: transportation, gathering,
processing, and storage of natural gas; marketing of energy and energy-related
commodities and products; generation of power; refining of petroleum; production
of chemicals; development and operation of energy infrastructure facilities;
exploration and production of natural gas and oil; and mining of coal.
El Paso's senior unsecured debt is rated Baa2 by Moody's and BBB by
Standard and Poor's.
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SUMMARY FINANCIAL INFORMATION OF PUBLIC SERVICE ELECTRIC AND EL PASO
We present below summary financial data for El Paso and Public Service
Electric as of and for each of the periods indicated.
Public Service Electric and El Paso are public companies which file
reports, proxy statements and other information, including financial reports,
with the SEC. See "Available Information."
The following is summarized financial information of Public Service
Electric and El Paso, and has been derived from their annual reports on Form
10-K for the year ended December 31, 2000. A copy of these annual reports on
Form 10-K can be obtained from the SEC. See "Available Information."
With respect to the summary financial data of Public Service Electric and
El Paso included in this prospectus, Cedar Brakes makes no representation as to
its accuracy or completeness or that there has not occurred any event which
would affect the accuracy or completeness thereof.
Public Service Electric and El Paso have neither guaranteed the payment of
principal or interest on the bonds nor the performance by Cedar Brakes of its
obligations with respect to the bonds. Although El Paso has entered into a
performance guaranty with us, pursuant to which El Paso has guaranteed to us the
punctual performance of all of El Paso Merchant's obligations under the power
services agreement and administrative services agreement, such performance
guaranty does not constitute a guaranty by El Paso of payment or performance on
the bonds nor any assurance by Public Service Electric or El Paso that we will
pay principal or interest on the bonds when such payments become due. Further,
if we fail to pay principal or interest on the bonds, El Paso will not be
obligated to make any such payments. As a result, the following financial
information is neither intended to indicate, nor should it be construed as an
indication, that Public Service Electric or El Paso will pay our obligations
under the bonds when they become due in the event we do not make such payments.
PUBLIC SERVICE ELECTRIC
SUMMARY CONSOLIDATED STATEMENTS OF INCOME
(IN MILLIONS)
YEAR ENDED DECEMBER 31,
------------------------
2000 1999 1998
------ ------ ------
Operating revenues.......................................... $5,888 $5,840 $5,568
Operating expenses.......................................... 4,620 4,242 4,157
------ ------ ------
Operating income............................................ 1,268 1,598 1,411
Other, net.................................................. (274) (435) (405)
------ ------ ------
Income from continuing operations before income tax
expense................................................... 994 1,163 1,006
Income taxes................................................ (407) (510) (404)
------ ------ ------
Income before extraordinary item............................ 587 653 602
Extraordinary item, net of income taxes..................... -- (804) --
------ ------ ------
Net income (loss)........................................... 587 (151) 602
Preferred stock dividends................................... (9) (9) (9)
------ ------ ------
Earnings (loss) available to Public Service Enterprise Group
Incorporated.............................................. $ 578 $ (160) $ 593
====== ====== ======
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PUBLIC SERVICE ELECTRIC AND GAS COMPANY
SUMMARY CONSOLIDATED BALANCE SHEETS
(IN MILLIONS)
DECEMBER 31,
-----------------
2000 1999
------- -------
ASSETS
Current assets.............................................. $ 1,491 $ 1,743
Property, plant, and equipment, net......................... 5,760 6,950
Other noncurrent assets..................................... 8,016 6,031
------- -------
Total assets................................................ $15,267 $14,724
======= =======
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities......................................... $ 2,644 $ 3,055
Long-term debt.............................................. 3,590 3,099
Noncurrent liabilities...................................... 3,835 4,136
Minority interest........................................... 683 683
Stockholders' equity........................................ 4,515 3,751
------- -------
Total liabilities and stockholders' equity.................. $15,267 $14,724
======= =======
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EL PASO CORPORATION
SUMMARY CONSOLIDATED STATEMENTS OF INCOME
(IN MILLIONS)
YEAR ENDED DECEMBER 31,
--------------------------
2000 1999 1998
------- ------- ------
Operating revenues.......................................... $21,950 $10,709 $9,560
Operating expenses.......................................... 20,619 10,742 9,795
------- ------- ------
Operating income (loss)..................................... 1,331 (33) (235)
Other, net.................................................. (463) (290) (241)
------- ------- ------
Income from continuing operations before income tax
expense................................................... 868 (323) (476)
Income tax expense (benefit)................................ 286 (81) (170)
------- ------- ------
Income (loss) before extraordinary items and cumulative
effect of accounting change............................... 582 (242) (306)
Extraordinary items, net of income taxes.................... 70 -- --
Cumulative effect of accounting change, net of income
taxes..................................................... -- (13) --
------- ------- ------
Net income (loss)........................................... $ 652 $ (255) $ (306)
======= ======= ======
Basic earnings (loss) per common share
Income (loss) before extraordinary items and cumulative
effect of accounting change............................ $ 2.53 $ (1.06) $(1.35)
Extraordinary items, net of income taxes.................. 0.30 -- --
Cumulative effect of accounting change, net of income
taxes.................................................. -- (0.06) --
------- ------- ------
Net income (loss)......................................... $ 2.83 $ (1.12) $(1.35)
======= ======= ======
Diluted earnings (loss) per common share
Income (loss) before extraordinary items and cumulative
effect of accounting change............................ $ 2.44 $ (1.06) $(1.35)
Extraordinary items, net of income taxes.................. 0.29 -- --
Cumulative effect of accounting change, net of income
taxes.................................................. -- (0.06) --
------- ------- ------
Net income (loss)......................................... $ 2.73 $ (1.12) $(1.35)
======= ======= ======
Basic average common shares outstanding..................... 230 228 226
======= ======= ======
Diluted average common shares outstanding................... 243 228 226
======= ======= ======
EL PASO CORPORATION
SUMMARY CONSOLIDATED BALANCE SHEETS
(IN MILLIONS)
DECEMBER 31,
-----------------
2000 1999
------- -------
ASSETS
Current assets.............................................. $10,076 $ 2,914
Property, plant, and equipment, net......................... 11,659 10,265
Other noncurrent assets..................................... 5,710 3,488
------- -------
Total assets................................................ $27,445 $16,667
======= =======
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities......................................... $10,467 $ 3,703
Long-term debt.............................................. 5,949 5,223
Deferred credits and other.................................. 4,504 3,101
Minority interest........................................... 2,956 1,693
Stockholders' equity........................................ 3,569 2,947
------- -------
Total liabilities and stockholders' equity.................. $27,445 $16,667
======= =======
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As a result of El Paso's merger with The Coastal Corporation on January 29,
2001, El Paso filed on March 23, 2001, a Current Report on Form 8-K, reflecting
supplemental combined financial data which include The Coastal Corporation
operations for all periods presented. Below is summarized information from that
report.
EL PASO CORPORATION
SUMMARY SUPPLEMENTAL COMBINED STATEMENTS OF INCOME
(IN MILLIONS)
YEAR ENDED DECEMBER 31,
---------------------------
2000 1999 1998
------- ------- -------
Operating revenues.......................................... $49,268 $27,332 $23,773
Operating expenses.......................................... 46,860 26,615 23,264
------- ------- -------
Operating income............................................ 2,408 717 509
Other, net.................................................. (634) (367) (336)
------- ------- -------
Income from continuing operations before income tax
expense................................................... 1,774 350 173
Income tax expense (benefit)................................ 538 93 (3)
------- ------- -------
Income from continuing operations........................... 1,236 257 176
Discontinued operations, net of income taxes................ -- -- (38)
------- ------- -------
Income before extraordinary items and cumulative effect of
accounting change......................................... 1,236 257 138
Extraordinary items, net of income taxes.................... 70 -- --
Cumulative effect of accounting change, net of income
taxes..................................................... -- (13) --
------- ------- -------
Net income before preferred stock dividends................. 1,306 244 138
Preferred stock dividends................................... -- -- 6
------- ------- -------
Net income available to common stockholders................. $ 1,306 $ 244 $ 132
======= ======= =======
Basic earnings per common share
Income from continuing operations available to common
stockholders........................................... $ 2.50 $ 0.52 $ 0.35
Discontinued operations, net of income taxes.............. -- -- (0.08)
Extraordinary items, net of income taxes.................. 0.14 -- --
Cumulative effect of accounting change, net of income
taxes.................................................. -- (0.03) --
------- ------- -------
Net income available to common stockholders............... $ 2.64 $ 0.49 $ 0.27
======= ======= =======
Diluted earnings per common share
Income from continuing operations available to common
stockholders........................................... $ 2.43 $ 0.52 $ 0.34
Discontinued operations, net of income taxes.............. -- -- (0.08)
Extraordinary items, net of income taxes.................. 0.14 -- --
Cumulative effect of accounting change, net of income
taxes.................................................. -- (0.03) --
------- ------- -------
Net income available to common stockholders............... $ 2.57 $ 0.49 $ 0.26
======= ======= =======
Basic average common shares outstanding..................... 494 490 487
======= ======= =======
Diluted average common shares outstanding................... 513 497 495
======= ======= =======
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EL PASO CORPORATION
SUMMARY SUPPLEMENTAL COMBINED BALANCE SHEETS
(IN MILLIONS)
DECEMBER 31,
-----------------
2000 1999
------- -------
ASSETS
Current assets.............................................. $14,819 $ 5,838
Property, plant, and equipment, net......................... 22,297 19,602
Other noncurrent assets..................................... 8,898 6,350
------- -------
Total assets...................................... $46,014 $31,790
======= =======
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities......................................... $15,675 $ 6,741
Long-term debt.............................................. 11,245 10,021
Deferred credits and other.................................. 7,268 5,700
Minority interest........................................... 3,707 2,444
Stockholders' equity........................................ 8,119 6,884
------- -------
Total liabilities and stockholders' equity........ $46,014 $31,790
======= =======
EL PASO MERCHANT
El Paso Merchant is an indirect wholly-owned subsidiary of El Paso that is
involved in a broad range of activities in the energy marketplace including
asset ownership, trading and risk management and financial services. El Paso
Merchant is one of North America's largest wholesale energy commodity marketers
and traders, and buys, sells and trades natural gas, power, crude oil, refined
products, coal and other energy commodities in the U.S. and internationally. El
Paso Merchant is also significant non-utility owner of electric generating
capacity with 84 facilities in 20 countries. El Paso Merchant's four refineries
have the capacity to process 538,000 barrels of crude oil per day and produce a
variety of gasolines and other products. El Paso Merchant also produces
agricultural and industrial chemicals and petrochemicals at seven facilities in
the U.S. and Canada. El Paso Merchant's coal operations produce high-quality,
bituminous coal with reserves in Kentucky, Virginia, and West Virginia. Most
recently, El Paso Merchant announced its expansion into the liquefied natural
gas business, capitalizing upon U.S. and worldwide demand for natural gas. The
financial services businesses of El Paso Merchant invest in emerging businesses
to facilitate growth in the U.S. and Canadian energy markets. As a global energy
merchant, El Paso Merchant evaluates and measure risks inherent in the markets
we serve, and use sophisticated systems and integrated risk management
techniques to manage those risks.
El Paso Merchant has a 24-hour trading, scheduling and dispatching
capability. For the first nine months in 2000, El Paso Merchant reported a
volume of approximately 87.1 million MW to the Federal Energy Regulatory
Commission and was ranked the thirteenth largest power marketer in terms of
volume of sales reported to the Federal Energy Regulatory Commission for this
period.
El Paso Merchant buys, sells, and trades power, power generation and
transmission capacity and other energy-related commodities and intermediates
risk in its markets using sophisticated integrated risk management techniques.
El Paso Merchant's merchant activities provide customers with flexible solutions
to meet their energy supply and financial risk management requirements by
utilizing its knowledge of the marketplace, natural gas pipelines and power
transmission infrastructure, supply aggregation, transportation management and
valuation, storage, and integrated price risk management. It also acquires,
develops, constructs, owns, operates and manages domestic power generation
facilities and other power related assets and joint ventures.
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El Paso Merchant and its affiliates have ownership interests or management
responsibilities in 40 power generation facilities with a total generating
capacity of over 5,000 megawatts.
LIMESTONE
Limestone indirectly owns approximately 80% of the ownership interests in
us, subject to increase upon specified events. Limestone is a statutory business
trust formed in 1999 under the laws of the State of Delaware. Limestone was
formed pursuant to the terms of the Limestone Trust Agreement among El Paso,
Wilmington Trust Company in its capacity as trustee, and Limestone, together
with a financial investor. The beneficial ownership interests of Limestone are
evidenced by approximately $150 million of Limestone trust certificates held by
institutional investors. El Paso has voting rights in Limestone with respect to
bankruptcy matters such as the filing of a voluntary bankruptcy petition.
Limestone was formed for the purpose of conducting limited activities, including
purchasing a membership interest in Chaparral, issuing senior notes in an
aggregate principal amount of approximately $1 billion and contributing most of
the proceeds of this issuance to Chaparral.
MESQUITE AND CHAPARRAL
Mesquite is our direct owner. Chaparral Investors, L.L.C. holds the sole
membership interest in Mesquite. In 1999, El Paso formed Chaparral to fund the
growth of its unregulated domestic power generation and related businesses.
Chaparral is a Delaware limited liability company, the members of which are El
Paso Chaparral Investor, L.L.C. and El Paso Chaparral Holding II Company, each
of which is a wholly-owned indirect subsidiary of El Paso, and Limestone.
Through Mesquite, Chaparral owns interests in (1) 22 commercially operating
gas-fired power facilities in New Jersey (including the Newark Bay Facility),
Rhode Island, Massachusetts, Colorado, Nevada and California and (2) one
gas-fired power facility under construction in Connecticut. These facilities in
the aggregate represent total generating capacity of approximately 3,300 MW, of
which El Paso affiliates have a net equity interest in approximately 1,930 MW.
El Paso Chaparral, a wholly-owned indirect subsidiary of El Paso, is the
managing member of Chaparral and will make all decisions on behalf of Chaparral
(except for actions requiring unanimous consent of the members).
CHAPARRAL MANAGEMENT
Pursuant to the Chaparral management agreement among the members of
Chaparral, Mesquite and Chaparral Management, Chaparral Management manages the
operations of Chaparral and Mesquite and, subject to the terms of the Chaparral
management agreement, manages the acquisition, operation and disposition of the
assets held by such entities. Chaparral Management is a wholly-owned indirect
subsidiary of El Paso.
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MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion contains forward-looking statements about us.
These statements are based on our current plans and expectations and involve
risks and uncertainties that could cause actual future results to be materially
different from those set forth in the forward-looking statements. Important
factors that could cause actual results to differ include risks set forth in
"Risk Factors" and "Forward-Looking Statements."
GENERAL
Our company has no employees and we are relying upon El Paso Merchant to
perform our obligations under our material agreements. Our material assets are
comprised of the amended power purchase agreement, receivables that are
generated by or accrue under the amended power purchase agreement, the proceeds
of such receivables, our interest in the amounts held in our accounts described
in this prospectus and our material agreements. We have no material obligations
other than those under the bonds, the indenture and our material agreements.
RESULTS OF OPERATIONS
We have included in this prospectus our audited financial statements, which
consist of a balance sheet dated as of December 31, 2000 and statements of
income, of cash flows and of member's capital from our formation, March 3, 2000,
through December 31, 2000. We were formed in March 2000, but did not begin
operations until September 27, 2000, when we acquired the power purchase
agreement. During the period from September 27, 2000 to December 31, 2000, we
generated revenues of $14.6 million from sales of electricity and capacity to
Public Service Electric. Operating expenses totaled $10.7 million, primarily
from payments to El Paso Merchant for purchases of power and for the
amortization of the amended power purchase agreement. Interest and debt expense
for the period was $7.1 million. Our net loss during this period was $3.1
million. Our operating expenses also include fees to El Paso Merchant under the
administrative services agreement. The annual fees to El Paso Merchant under the
administrative services agreement are established in our agreements and are
initially a total of $0.1 million annually. These fees to El Paso Merchant
accrue annually, but are only payable to the extent that there are amounts on
deposit in the collections account after payment of all current and past due
amounts having a payment priority ranking above these fees. See "Summary of Our
Transaction Documents -- Administrative Services Agreement -- Fee."
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Under the amended power purchase agreement, electricity rates are set
annually in accordance with a schedule to the amended power purchase agreement.
The following table sets forth the amount of annual energy deliveries, the rates
at which we purchase electricity from El Paso Merchant and the rates we receive
when we sell electricity to Public Service Electric:
CONTRACT RATE
($ PER MWH)
PAYABLE BY
PUBLIC SERVICE CONTRACT RATE ($ PER
ELECTRIC TO US MWH) PAYABLE BY US
ANNUAL ENERGY UNDER AMENDED TO EL PASO MERCHANT
DELIVERIES QUANTITY POWER PURCHASE UNDER POWER SERVICES
CONTRACT YEAR (MWH) AGREEMENT AGREEMENT
- ------------- ------------------- -------------- --------------------
2001................................ 788,954 $72.17 $29.71
2002................................ 788,954 73.53 29.30
2003................................ 811,229 74.64 28.56
2004................................ 855,779 75.44 27.94
2005................................ 855,779 76.96 28.07
2006................................ 855,779 78.74 28.26
2007................................ 855,779 80.34 28.26
2008................................ 855,779 82.13 28.80
2009................................ 855,779 83.88 29.08
2010................................ 855,779 85.76 29.36
2011................................ 855,779 87.67 29.64
2012................................ 855,779 89.63 29.64
2013................................ 570,519 92.43 33.75
The maximum amount of the annual energy payments for any year can be
readily determined. Payments to us under the amended power purchase agreement
are determined by multiplying the contract rate by the amount of energy
delivered.
Our results of operations in the future will depend primarily on revenues
from the sale of energy and capacity and the level of our expenses. There can be
no assurance that we can find alternative buyers in the event of the termination
of the amended power purchase agreement, the loss of which would accordingly
have a material affect on our business.
RECENT ACCOUNTING PRONOUNCEMENTS
In June 1998, the Financial Accounting Standards Board issued SFAS No. 133,
Accounting for Derivative Instruments and Hedging Activities. In June of 1999,
the FASB extended the adoption date of SFAS No. 133 through the issuance of SFAS
No. 137, Deferral of the Effective Date of FASB Statement No. 133. In June 2000,
the FASB issued SFAS No. 138, Accounting for Certain Derivative Instruments and
Certain Hedging Activities, which also amended SFAS No. 133. SFAS No. 133, and
its amendments and interpretations, establishes accounting and reporting
standards for derivative instruments, including certain derivative instruments
embedded in other contracts, and for hedging activities. It will require that we
measure all derivative instruments at their fair value, and classify them as
either assets or liabilities on our balance sheet, with a corresponding offset
to income or other comprehensive income depending on their designation, their
intended use, or their ability to qualify as hedges under the standard. We
adopted SFAS No. 133 on January 1, 2001, and applied the standard to all
derivative instruments that existed on that date, which included our amended
power purchase agreement and power services agreement.
The impact of adopting SFAS No. 133 resulted in an increase to our assets
and a credit to net income of approximately $89.4 million. This impact is based
upon the expected cash receipts (payments) derived from the power purchase
agreement and the power services agreement compared to our estimate of future
power prices in the respective markets. Estimates of the future prices of power
are based on the forward pricing curve of the appropriate interconnect and this
curve is derived from actual prices observed in the market, price quotes from
brokers and extrapolation models. The effect of adopting SFAS No. 133
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has been classified as a cumulative effect of a change in accounting principle
in our 2001 financial statements.
LIQUIDITY AND CAPITAL RESOURCES
We have no capital requirements, either in the short or long term. We
believe that cash flows from operations will be sufficient to satisfy our cash
and liquidity requirements, including the payments of interest and principal on
the bonds and the payment of our operating expenses, although there can be no
assurance that this will be the case.
Our sole source of liquidity and capital resources is the payments to be
made by Public Service Electric under the amended power purchase agreement,
shortfall payments and excess amounts required to be paid to us by El Paso
Merchant under the power services agreement and guaranteed by El Paso under the
El Paso performance guaranty, and amounts on deposit in the liquidity account or
acceptable credit support provided in place of cash deposits. We are prohibited
by the indenture from incurring additional indebtedness. We would, thus, be
unable to make up any shortfalls in cash through additional borrowing to pay
amounts due under the bonds. All scheduled payments of principal and interest on
the bonds have been calculated so as to be paid solely from the collections
account payments to be made each year by Public Service Electric for the full
amount of the annual energy deliveries.
Pursuant to the amended power purchase agreement, we have the right to
schedule and deliver amounts of energy up to the annual energy deliveries for
each year. In order to meet our payments of principal and interest on the bonds,
El Paso Merchant is required, pursuant to the power services agreement, to
schedule and deliver the full amount of the annual energy deliveries during each
year. Payments received from Public Service Electric for minimum energy
deliveries will not be sufficient to cover amounts due under the bonds.
The annual energy deliveries may be scheduled and delivered at any time
during the calendar year (subject to meeting the minimum energy deliveries
requirement, prior notification provisions and maximum delivery rate limits).
Although our revenues, determined on an annual basis, should remain stable, our
monthly revenues may vary significantly. We receive our last monthly payment
from Public Service Electric for each year on January 31 of the following
calendar year. Interest payments are made semi-annually, each February 15 and
August 15 of each year and principal payments are made annually on February 15
of each year.
In order to offset any timing differences between our cash flows from the
energy deliveries, which may be received on an irregular basis, and our interest
and principal payments on the bonds, we funded the liquidity account with the
trustee in an amount equal to the liquidity reserve required balance out of the
proceeds of the offering of the Series A bonds. The purpose of the liquidity
account is to provide the trustee the necessary cash to fund a payment equal to
the maximum amount of interest that will be due on any subsequent interest
payment date. If we have not scheduled and delivered enough energy during any
six month period from January through July to make the interest payment due on
the interest payment date in August, we will be able to withdraw amounts from
the liquidity account or seek to make this payment to the extent that funds are
in the liquidity account. Similarly, if we do not have sufficient funds in the
collections account to pay the principal payment due on the principal payment
date in February, we will be able to draw on the funds available in the
liquidity account. Once funds have been withdrawn from the liquidity account,
those funds will only be replenished out of funds otherwise available in the
collections account. If surplus funds are not available from the collections
account, the liquidity reserve required balance will not be maintained.
El Paso has the right from time to time to withdraw all or a portion of the
cash on deposit in the liquidity account if El Paso replaces that cash with
acceptable credit support. This is described in "The Energy Sales
Transactions -- Accounts."
Assuming that we schedule and deliver all of the annual energy deliveries
each year, the minimum debt service coverage ratio for any year is expected to
be 1.03 to 1.00 and the average debt service
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coverage ratio for any year is expected to be 1.03 to 1.00. The following table
sets forth on an annual basis cash available for debt service and debt service
for the bonds commencing in the year 2000.
CASH AVAILABLE FOR DEBT
YEAR DEBT SERVICE(1) SERVICE(2)
- ---- ------------------- ----------
(IN MILLIONS)
2000...................................................... $11.3(3) $11.0
2001...................................................... 33.2 32.3
2002...................................................... 34.8 33.8
2003...................................................... 37.4 36.3
2004...................................................... 40.8 39.6
2005...................................................... 42.1 40.9
2006...................................................... 43.6 42.3
2007...................................................... 45.0 43.7
2008...................................................... 46.2 44.9
2009...................................................... 47.6 46.2
2010...................................................... 49.1 47.7
2011...................................................... 50.7 49.0
2012...................................................... 52.3 50.7
2013...................................................... 35.0 34.0
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(1) Determined from February 1 to January 31 of the following year. The
information presented in the table regarding cash available for debt service
is based upon the assumptions that the full amount of the annual energy
deliveries are scheduled and delivered each year and the energy deliveries
are purchased at the rates set forth in the power services agreement and
sold at the rates set forth in the amended power purchase agreement.
(2) Determined from February 16 to February 15 of the following year. The
information presented in the table regarding debt service is based upon a
principal amount of $310 million, an interest rate of 8.50% and the
amortization schedule presented elsewhere under "Description of the Bonds."
(3) Includes an initial deposit of $2,396,509 to the collections account from
the proceeds of the offering of the Series A bonds.
Our projection of a minimum debt service coverage ratio of 1.03 to 1.00 is
also based upon the assumptions that El Paso Merchant will pay the liquidated
damage payments that would be required in the event that it is unable to fulfill
its obligations under the power services agreement. See "Summary of Our
Transaction Documents -- Power Services Agreement." El Paso Merchant may be
required to pay us excess amounts in the event that they fail to deliver the
minimum energy deliveries, schedule energy deliveries or deliver energy at the
contractually specified delivery point. If, for example, El Paso Merchant has
not delivered any of the energy scheduled for delivery that month, it will be
required to pay us an amount determined by reference to Public Service
Electric's cost of replacement energy for that month. See "Summary of Our
Transaction Documents -- Power Services Agreement -- Delivery of Capacity and
Energy -- Our Failure to Deliver Energy and Capacity." If El Paso Merchant or El
Paso is unable to pay these excess amounts, we may be unable to pay
corresponding amounts that we are required to pay Public Service Electric under
the amended power purchase agreement.
Further, if El Paso Merchant does not schedule and deliver the annual
energy deliveries to us in any year, it will be required to pay to us shortfall
payments. See "Summary of Our Transaction Documents -- Power Services
Agreement -- Delivery of Capacity and Energy -- Shortfall Payments." These
shortfall payments are sized so that they are equivalent to the shortfall
between our expected revenues under the amended power purchase agreement
assuming the full delivery of the annual energy deliveries, and the actual
amount of energy deliveries made during that year. If El Paso Merchant or El
Paso is unable to pay shortfall payments, we may be unable to make payments on
the bonds.
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Pursuant to the indenture, payments to the bondholders are given priority
over payments to our members. Under the indenture, we are permitted to make
distributions to our members on February 15th of each year, provided that no
default or event of default exists and the debt service coverage test of 1.03 to
1.0 is met. We expect that all excess cash flow (after the payment of debt
service, operating expenses and deposits to the liquidity account) will be
distributed annually to our members, as permitted by the indenture.
FORWARD-LOOKING STATEMENTS
Some statements contained in this prospectus are forward-looking
statements. These forward-looking statements can be identified by the use of
words such as "expect," "intend," "plan," "project," "believe," "estimate" and
similar expressions. We have based these forward-looking statements on our
current expectations, and our and the independent energy consultant's
projections about future events based upon our knowledge of facts as of the date
of this prospectus and the independent energy consultant's assumptions about
future events. These forward-looking statements are subject to various risks and
uncertainties that may be outside our control and that may result in actual
results differing materially from projected results. These risks and
uncertainties, including those described under "Risk Factors," indicate, among
other things:
- market volatility due to world and regional events;
- U.S. and world economic conditions;
- the enforceability of our contracts;
- governmental, statutory or regulatory changes or initiatives affecting us
or our contracts; and
- other unpredictable or unknown factors not discussed.
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REGULATION OF THE ELECTRIC INDUSTRY
The following is a summary overview of the industry and applicable
regulations and shall not be considered a full statement of all issues
pertaining thereto.
Historically, the electric utility industry in the United States was
composed primarily of investor-owned utilities, municipal utilities, rural
electric cooperatives and various federal power agencies, including the
Tennessee Valley Authority. These entities have traditionally been the only
significant providers of electric power to retail and wholesale customers.
Further, traditional electric utilities in the United States were
vertically-integrated businesses that owned generation, transmission and
distribution facilities and whose operations were comprehensively regulated by
federal and state governments using a cost-of-service framework. For many
investor-owned utilities, the generation of electricity has traditionally been
dominant in terms of assets employed, capital invested and revenue generated.
However, the structure and operation of the electric industry is changing as a
result of increasing competition and changing regulation.
TRADITIONAL ELECTRIC UTILITY INDUSTRY REGULATION
Electric utilities have historically been highly regulated by both state
public utility commissions and the Federal Energy Regulatory Commission. State
regulatory authorities exercise their jurisdiction over almost all aspects of
utility operation. The Federal Energy Regulatory Commission regulates wholesale
sales of electric power and the transmission of electricity in interstate
commerce pursuant to the Federal Power Act and regulations promulgated under the
Federal Power Act. Pursuant to its authority under the Federal Power Act, the
Federal Energy Regulatory Commission subjects public utilities to rate and
tariff regulation and accounting and reporting requirements, as well as
oversight of mergers and acquisitions, securities issuances and dispositions of
facilities.
Under the Public Utility Holding Company Act of 1935 ("PUHCA"), any company
that directly or indirectly owns, controls or holds with the power to vote ten
percent (10%) or more of the outstanding voting securities of a "public utility
company," or is a company that is a "holding company" of a public utility
company, must register with the SEC unless it is eligible for an exemption or
unless an appropriate application is filed with, and an order is granted by, the
SEC declaring it not to be a holding company. PUHCA requires registered public
utility holding companies to limit their operations to single integrated utility
systems and to divest any other operations not functionally related to the
operation of the utility system. A registered holding company and its
subsidiaries under PUHCA are subject to financial and organizational regulation,
including SEC approval of their financing transactions. Although the SEC has not
had occasion to consider the treatment of power marketers under PUHCA, the SEC
staff has consistently stated in "no-action" letters that it would not recommend
enforcement action under PUHCA against power marketers that do not own a
physical power plant. Based on such letters, we do not believe we are subject to
PUHCA. Since El Paso Merchant and its affiliates do not own physical power
plants (except those that are exempt from PUHCA as Exempt Wholesale Generators
or Foreign Utility Companies under sections 32 or 33 of PUHCA, or as Qualifying
Facilities under PURPA that are exempt from PUHCA) and do not own other physical
assets that would be jurisdictional under PUHCA, we also do not believe that
either El Paso Merchant or any of our affiliates is subject to PUHCA.
PURPA reduced regulatory constraints and encouraged entities other than
utilities to enter the electric power generation business. Independent power
producers and cogenerators satisfying the Federal Energy Regulatory Commission's
standards as qualifying facilities became exempt from PUHCA, most provisions of
the Federal Power Act and state laws previously applicable relating to rate,
organizational and financial regulation. PURPA also required electric utilities
to purchase electricity generated by qualifying facilities at a price based on
the utility's avoided cost of purchasing electricity or generating electricity
itself, and to sell supplementary, back-up, maintenance and interruptible power
to qualifying facilities on a just and reasonable and non-discriminatory basis.
The implementation of PURPA created a new class of non-utility generating
companies and a significant market for electric power produced by non-utilities.
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ELECTRIC INDUSTRY DEREGULATION AND RESTRUCTURING
The Energy Policy Act of 1992 (the "EP Act") engendered more competition in
the electric industry. The EP Act permitted independent generation companies
that met specific requirements to sell wholesale power to utilities without
becoming subject to PUHCA. As a result, the competition increased among
companies selling power to utilities. The EP Act also expanded the Federal
Energy Regulatory Commission's authority to increase competition at the
wholesale level by granting the Federal Energy Regulatory Commission the
authority to require utilities to provide access to their transmission lines,
upon request, to specified entities seeking to transmit power to wholesale
purchasers.
Legislation to restructure the electric industry is under active
consideration at the federal level, and several states have passed, or are
actively considering, restructuring legislation. Congress is considering
legislation that would modify federal laws affecting the electric industry.
Bills have been introduced in the Senate and the House of Representatives that
would, among other things, provide retail electric customers with the right to
choose their electricity providers. Modifications to PURPA and PUHCA have also
been proposed. Although the legislative and regulatory proposals vary, several
common themes have developed. These themes include the availability of market
pricing, retail customer choice of electric supplier, recovery of stranded
costs, deregulation of generation and separation of generation assets from
transmission, distribution and other assets.
As a result of these initiatives, it is now widely believed that the
generation of electricity will be deregulated and opened up to competition.
Electricity is expected to be traded as a commodity, and generators are expected
to compete primarily in terms of price. Participants in the commodity market are
expected to include electric utilities, power marketers, independent power
producers and commodity trading firms.
Many utilities have functionally separated their generation, transmission
and distribution operations (often called "disaggregation" or "unbundling") to
prepare for possible deregulation of generation. A number of electric utilities
have announced or completed plans to divest their generation assets. As a
result, the participants in the electricity generation market for the
foreseeable future are expected to include captive subsidiaries of
vertically-integrated utilities, non-utility generators with contracts to sell
power to utilities and merchant plants not subject to cost-of-service
regulation, as well as marketers of generation services.
The transmission and distribution of electricity, viewed to be natural
monopoly functions, are expected to remain regulated. In general, it is expected
that the utility regulators in each state will remain responsible for regulating
the distribution of electricity, while the Federal Energy Regulatory Commission
is expected to supervise the transmission of electricity.
In light of recent legislative and regulatory initiatives, power marketers
have emerged as intermediaries that buy electric energy and/or capacity,
transmission, ancillary services and other commodities and services from
traditional utilities and others and resell these commodities and services on a
wholesale basis. Unlike traditional utilities, power marketers often own neither
generation nor transmission facilities and have no franchised service area.
Wholesale power marketers, such as El Paso Merchant, are subject to Federal
Energy Regulatory Commission jurisdiction under the Federal Power Act regarding
rates, terms and conditions of service and specified reporting requirements.
Because the Federal Power Act grants the Federal Energy Regulatory Commission
jurisdiction over wholesale electric sales, a power marketer that desires to
sell electricity on a wholesale basis must have its rates accepted for filing by
the Federal Energy Regulatory Commission. Wholesale power marketers with rates
on file at the Federal Energy Regulatory Commission are considered public
utilities for the purpose of the Federal Power Act. A power marketer may receive
Federal Energy Regulatory Commission authorization to make interstate wholesale
power sales at market-based rates if it does not own or control generation or
transmission facilities that could provide it with market power. Power marketers
are subject to other regulatory requirements, such as the filing of quarterly
and annual reports with the Federal Energy Regulatory Commission and notifying
the Federal Energy Regulatory Commission of any significant
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change in operations or applying for Federal Energy Regulatory Commission
approval of a change in corporate structure.
A major additional development in the move to a more competitive electric
power industry occurred when the Federal Energy Regulatory Commission issued its
Order Nos. 888 and 889, which contained final rules that introduced competitive
reforms into the wholesale power market and reduced regulatory constraints. At
the core of the new rules is a price-regulated transmission sector that provides
service completely separated or "unbundled" from generation and supply. Under
the new rules, all wholesale buyers and sellers of power, including the
utilities themselves, are required to take transmission service pursuant to the
same pro-forma tariff on the same terms and conditions and at the same prices.
Order No. 888 required utilities subject to the Federal Energy Regulatory
Commission's jurisdiction to provide access across their transmission systems to
third parties and allowed them to seek recovery as "stranded costs" from
departing wholesale customers, the revenues that the utilities expected to
receive from those customers. The Federal Energy Regulatory Commission also
imposed reciprocity requirements that compel non-jurisdictional utilities (e.g.,
public power, government-owned power marketing administrations or members of the
Electric Reliability Council of Texas) to offer the same quality of service as a
condition to their eligibility to take advantage of open-access transmission by
Federal Energy Regulatory Commission-regulated utilities. Order No. 888 also
required power pools, or associations of interconnected electric transmission
and distribution systems that have an agreement for integrated and coordinated
operations, to provide open-access transmission. Under Order No. 889, public
utilities must provide the public with an electronic system for buying and
selling transmission service in transactions with the utilities and abide by
specific standards of conduct when using their transmission system to make
wholesale sales of power. The Federal Energy Regulatory Commission has acted on
rehearing of Order Nos. 888 and 889, and they are currently the subject of a
federal appeal. In addition, the Federal Energy Regulatory Commission has
recently issued Order No. 2000, affirmed by Order 2000-A, which encourages the
creation of regional transmission groups throughout the country.
STATE REGULATION
The New Jersey Board of Public Utilities exercises regulatory jurisdiction
over New Jersey's "public utilities." A "public utility" is defined as including
every individual, corporation, partnership or association and their lessees,
trustees or receivers that own, operate, manage or control within New Jersey any
electricity distribution system for public use.
The New Jersey Board of Public Utilities has jurisdiction over a public
utility to regulate its rates and service, the assumption by it of liabilities
and obligations and the issuance and sale of some of its securities. This
regulatory jurisdiction includes the power to regulate a public utility's
earnings, fix its rates, and authorize it to recover specific costs from its
ratepayers. The New Jersey Board of Public Utilities' jurisdiction over an
electric public utility is limited to prescribing uniform systems of accounts,
conservation and reliability measures, service territory, filing of periodic
reports and, with respect to retail sales, rate structure. The New Jersey Board
of Public Utilities does not have jurisdiction to regulate the earnings or fix
the rates of an electric public utility that is not a public utility.
A New Jersey investor-owned electric utility serving the public at retail,
such as Public Service Electric, is subject to broad New Jersey Board of Public
Utilities regulatory jurisdiction, both as a public utility and as an electric
public utility. By comparison, an entity that supplies electricity on a
wholesale basis only is not subject to New Jersey Board of Public Utilities
regulation as a public utility. These entities, however, may be subject to the
New Jersey Board of Public Utilities' limited regulatory jurisdiction if they
supply electricity on the retail level and fall within the statutory definition
of "electric power supplier."
Since we will not make retail sales of electricity in New Jersey, we will
not be subject to New Jersey Board of Public Utilities regulation as an
"electric power supplier." Since we do not anticipate that we will own, maintain
or operate an electric generation, transmission or distribution system in New
Jersey, we do
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not believe that we will be subject to New Jersey Board of Public Utilities
regulation as an "electric public utility."
THE FEDERAL ENERGY REGULATORY COMMISSION ORDERS
The Federal Energy Regulatory Commission approved our request to sell
electricity at negotiated rates on July 12, 2000, and that approval order also
granted pre-approval for us to issue bonds and assume liabilities. The Federal
Energy Regulatory Commission order became final and nonappealable on August 12,
2000.
THE NEW JERSEY BOARD OF PUBLIC UTILITIES ORDER
The amended power purchase agreement amends and restates a purchase
agreement that Public Service Electric entered into with Newark Bay pursuant to
PURPA. See "Summary of Our Transaction Documents -- amended power purchase
agreement." The New Jersey Board of Public Utilities previously authorized
Public Service Electric to recover the costs of this qualifying facility
agreement from its ratepayers. Since the amended power purchase agreement amends
and restates the qualifying facility agreement under which the New Jersey Board
of Public Utilities previously authorized Public Service Electric's recovery of
costs, Public Service Electric filed with the New Jersey Board of Public
Utilities a petition seeking confirmation that the amended power purchase
agreement similarly qualifies for cost recovery under New Jersey law. The
amended power purchase agreement, as a wholesale power sales agreement, itself
is not subject to New Jersey Board of Public Utilities jurisdiction, and Public
Service Electric did not seek New Jersey Board of Public Utilities' approval of
the agreement for any purpose other than to confirm cost recovery. On July 7,
2000, the New Jersey Board of Public Utilities issued its order approving the
amended power purchase agreement for cost recovery purposes. This order became
final and non-appealable on September 26, 2000.
THE ENERGY SALES TRANSACTIONS
GENERAL
Our company purchased the original power purchase agreement from Newark Bay
pursuant to a purchase and sale agreement. The original power purchase agreement
was amended and restated immediately upon its transfer to us. The proceeds of
the offering of the Series A bonds were used to pay the purchase price for the
original power purchase agreement and transaction costs (such as legal and
advisory costs and fees) and to fund the liquidity account. See "Use of
Proceeds."
Newark Bay owns the Newark Bay Facility. Newark Bay is an affiliate of
ours. Pursuant to the original power purchase agreement, Newark Bay sold
generating capacity and associated energy from the Newark Bay Facility to Public
Service Electric. Under the original power purchase agreement, the Newark Bay
Facility was required to be a qualifying facility under PURPA. The managers of
Newark Bay and of Public Service Electric sought to amend the original power
purchase agreement in order to achieve a number of benefits, including the
elimination of this requirement that we must source capacity and energy only
from the Newark Bay Facility. The elimination of the requirement that the Newark
Bay Facility be the only source of energy under the amended power purchase
agreement is beneficial to us because we can source energy from anywhere in the
PJM market, and the cost of energy sourced in this way may be less expensive
than the cost to produce such energy at the Newark Bay Facility. The benefits of
the amended power purchase agreement also include significantly more flexibility
in scheduling energy deliveries, including a greater degree of daily delivery
flexibility and, from the perspective of Public Service Electric, the
substantial reduction of the energy and capacity rates under the amended power
purchase agreement from those under the original power purchase agreement.
Newark Bay agreed to sell the original power purchase agreement to us and
we paid Newark Bay the purchase price out of the proceeds of the offering of the
Series A bonds. The amendment of the original power purchase agreement became
effective on September 26, 2000. The sale of the original power
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purchase agreement by Newark Bay to us was effected in order to optimize the
size and pricing of the bond offering, to reduce the risk to holders of any
liabilities incurred by Newark Bay as a result of its ownership of physical
assets and to reduce the risk of consolidation of the original power purchase
agreement in the event of the bankruptcy of Newark Bay.
We expect that interest and principal on the bonds will be paid solely from
capacity and energy payments from Public Service Electric to us under the
amended power purchase agreement (as supplemented, if revenues from these
capacity and energy payments are not available on any interest or principal
payment date, by funds in the liquidity account). All scheduled payments of
principal and interest on the bonds have been calculated so as to be paid from
the total amount of payments that we expect to receive each year from Public
Service Electric. We have entered into the power services agreement and the
administrative services agreement with El Paso Merchant in order to have El Paso
Merchant perform all of our obligations and exercise all of our rights in
accordance with all of our material agreements and the indenture and the related
financing documents under which the Series A bonds were issued and the Series B
bonds will be issued. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
AMENDED POWER PURCHASE AGREEMENT
Under the amended power purchase agreement, which has a term expiring
August 31, 2013, we are required to deliver the minimum energy deliveries.
Further, under the amended power purchase agreement, we have the right to
schedule and deliver at any time during the year (subject to prior notification
provisions and delivery rate requirements) additional energy deliveries. If we
deliver energy at the rate of 150MW/hour (the maximum permitted under ordinary
circumstances), the minimum energy deliveries will only require us to deliver
during 77% of the on-peak hours during the summer months and 56% of the on-peak
hours of the other months. Although we are not required to schedule any
additional energy deliveries under the amended power purchase agreement, in
order for us to have sufficient funds to pay principal and interest on the
bonds, we must deliver the full amount of the annual energy deliveries each
year, since the minimum energy deliveries are not sufficient to cover the
amounts due under the bonds. In addition to the minimum energy deliveries, under
the amended power purchase agreement we are required to make available to Public
Service Electric the reserved capacity so as to enable Public Service Electric's
account with PJM to reflect this reserved capacity. We are allowed to provide
Public Service Electric with reserved capacity and energy deliveries from any
source of supply connected to the PJM market, including, but not limited to, the
Newark Bay Facility.
The amended power purchase agreement requires Public Service Electric to
pay us each month a combined payment for the capacity and energy provided by us.
The amount of the payment is based, in part, on the amount of energy we actually
deliver. The monthly payments are deposited by Public Service Electric directly
into a collections account established by the trustee under the indenture under
which the Series A bonds were issued and the Series B bonds will be issued.
Amounts in the collections account must be used in the order of priority
specified under "Description of the Bonds -- Withdrawals from the Collections
Account." Payments of interest and principal on the bonds will be made solely
from amounts in the collections account (and in some limited circumstances, from
funds in the liquidity account; see "Description of the Bonds -- The Accounts").
The amount payable to us by Public Service Electric in any month will be reduced
by a credit to Public Service Electric if we fail to deliver all or part of the
energy scheduled for delivery or we fail to schedule and deliver the minimum
energy deliveries. The amount payable by Public Service Electric in any month
will also be reduced by a credit to Public Service Electric if we do not deliver
energy at the Newark Bay Facility or at other locations specified in the amended
power purchase agreement or if we fail to provide all or part of the reserved
capacity to Public Service Electric. Any such failure would reduce the funds
available to make payments on the bonds during the relevant period in the event
that El Paso Merchant and El Paso fail to perform their obligations under the
power services agreement or the El Paso performance guaranty, respectively. See
"Summary of Our Transaction Documents -- Power Services Agreement" and "Summary
of Our Transaction Documents -- El Paso Performance Guaranty."
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POWER SERVICES AGREEMENT
In order to meet our obligations to provide reserved capacity and to
deliver energy under the amended power purchase agreement, we have entered into
the power services agreement with El Paso Merchant, which became effective on
September 26, 2000. Under the power services agreement, El Paso Merchant must
make available to us capacity credits equal to the reserved capacity and must
schedule and deliver the full amount of the annual energy deliveries during each
year. As is the case with us under the amended power purchase agreement, El Paso
Merchant may deliver energy to us at any point within the PJM market.
In consideration for the reservation of capacity and delivery of energy by
El Paso Merchant, we must make combined monthly energy and capacity payments to
El Paso Merchant. Our monthly payments to El Paso Merchant under the power
services agreement will be reduced by a credit to us in the event that El Paso
Merchant fails to schedule and deliver the minimum energy deliveries or to
deliver energy as scheduled, El Paso Merchant does not deliver energy at the
Newark Bay Facility or at other specified locations or if El Paso Merchant fails
to provide all or part of the reserved capacity to us. These credits will be
calculated in the same manner and applied in the same months in which the
corresponding credits are applied to Public Service Electric under the amended
power purchase agreement. If at the end of any month, the amount of the credits
due to us is greater than the total amount that we owe to El Paso Merchant for
that month, El Paso Merchant will be obligated to pay us in cash these excess
amounts.
If El Paso Merchant does not schedule and deliver the annual energy
deliveries to us in any year, El Paso Merchant will be required to pay to us by
February 10th of the following year the shortfall payments. In addition to the
shortfall payments, El Paso Merchant will also be required to pay into a damages
and indemnity account other damages and indemnity payments (such as for
third-party liability) and distribution surcharges that we may be liable for
under the amended power purchase agreement. We or El Paso Merchant have the
right to terminate the power services agreement upon 10 days written notice if
we do not pay amounts that we owe to El Paso Merchant within 30 days of El Paso
Merchant's notice to us that our payment is overdue. We or El Paso Merchant may
also terminate the power services agreement upon 10 days written notice if the
amended power purchase agreement terminates as the result of a bankruptcy or
other default of Public Service Electric. The other provisions of the amended
power purchase agreement and the power services agreement, including the terms
during which they are effective, are substantially similar to each other. See
"Summary of Our Transaction Documents -- Power Services Agreement." For more
information about the provisions of the amended power purchase agreement and the
power services agreement, see "Summary of Our Transaction Documents" below.
El Paso Merchant expects to reserve capacity and procure energy to be
delivered on our behalf under the power services agreement from energy procured
from the PJM market. For more information about the PJM market, see "Independent
Energy Consultant" and Annex A.
ADMINISTRATIVE SERVICES AGREEMENT
We have also entered into an administrative services agreement with El Paso
Merchant pursuant to which El Paso Merchant has agreed:
- to perform all of our administrative and management obligations under the
amended power purchase agreement, exercise all of our rights under the
power services agreement and coordinate our operations under both
agreements;
- to perform all of our administrative and managerial functions under our
material agreements, the indenture and the related financing documents;
and
- to notify El Paso Merchant and El Paso of their payment obligations under
the power services agreement and the El Paso performance guaranty,
respectively.
For more detailed information about the administrative services agreement, see
"Summary of Our Transaction Documents -- Administrative Services Agreement."
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EL PASO PERFORMANCE GUARANTY
El Paso has entered into a performance guaranty pursuant to which El Paso
has agreed to unconditionally guarantee all obligations (including payment
obligations) of El Paso Merchant under the power services agreement and the
administrative services agreement.
For more detailed information about the El Paso performance guaranty, see
"Summary of Our Transaction Documents -- El Paso Performance Guaranty."
ACCOUNTS
Payments by Public Service Electric under the amended power purchase
agreement, shortfall payments and excess amounts paid by El Paso Merchant
pursuant to the power services agreement or by El Paso pursuant to the El Paso
performance guaranty and transfer payments from the liquidity account must be
deposited directly into the collections account. A portion of the proceeds of
the offering of the Series A bonds was deposited into the collections account.
The trustee must disburse funds from the collections account to pay our expenses
(including capacity and energy payments to El Paso Merchant and principal and
interest on the bonds) in a specific order of priority. See "Description of the
Bonds -- Withdrawals from the Collections Account."
In order to offset any timing difference between our cash flows from the
additional energy deliveries, which we may receive on an irregular basis
throughout the year, and our interest payments on the bonds, which we must make
semi-annually, we have provided for the setting up and funding of the liquidity
account with the trustee in an amount equal to the liquidity reserve required
balance. Amounts on deposit in the liquidity account may also be used to pay
principal if we do not have sufficient funds in the collections account to pay
these amounts. If either the letter of credit issuing bank or El Paso, as
applicable, has the required credit rating, El Paso may substitute acceptable
credit support for amounts deposited in the liquidity account. See "Description
of the Bonds -- The Accounts."
If we are required to pay to third-parties damages or indemnity amounts
arising under the amended power purchase agreement, El Paso Merchant may be
required to pay us these amounts. Those amounts will be paid into, and the
corresponding payment to Public Service Electric will be disbursed from, the
damages and indemnity account. See "Description of the Bonds -- The Accounts."
SECURITY OWNERSHIP OF OUR OWNERS
CEDAR BRAKES I, L.L.C.
The following table sets forth information concerning our owners.
PERCENT OF
NATURE OF PERCENT OF TOTAL VOTING
NAME AND ADDRESS OWNERSHIP INTEREST OWNERSHIP POWER
- ---------------- ------------------ ---------- ------------
Mesquite Investors, L.L.C...................... Member 100 100
c/o El Paso Corporation
1001 Louisiana Street
Houston, Texas 77002
MESQUITE
Mesquite is an indirect wholly owned subsidiary of El Paso and Limestone.
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SUMMARY OF OUR TRANSACTION DOCUMENTS
The following is a summary of selected provisions of some of the principal
documents related to our transaction and should not be considered to be a full
statement of the terms and provisions of those agreements. Accordingly, the
following summaries are qualified by reference to each agreement and are subject
to the terms of the full text of each agreement. Unless otherwise stated, any
reference in this prospectus to any agreement will mean the agreement described
and all schedules, exhibits and attachments thereto as amended, restated,
supplemented or otherwise modified (including by any consent and agreement
required in connection with the financing contemplated in this prospectus) and
to be in effect as of the date of this prospectus. We encourage you to read
these agreements, copies of which will be available for inspection at our
principal executive offices or upon written request of any potential investor.
AMENDED POWER PURCHASE AGREEMENT
We entered into the amended power purchase agreement with Public Service
Electric on March 21, 2000. The amended power purchase agreement amends and
restates a power purchase agreement between Newark Bay and Public Service
Electric, and provides that we must sell capacity and energy to Public Service
Electric.
TERM
The amended power purchase agreement became effective on September 26, 2000
and remains in effect through and including August 31, 2013 unless terminated
earlier as provided in the amended power purchase agreement.
PURCHASE AND SALE OF CAPACITY AND ENERGY
General Condition of Delivery and Acceptance of Energy and Capacity
We may provide energy and capacity to Public Service Electric at our option
from any source of supply, including the Newark Bay Facility or other sources.
Qualifying Facility Status
Our obligations and Public Service Electric's obligations under the amended
power purchase agreement to buy and sell capacity and energy is not conditioned
in the amended power purchase agreement upon our maintenance of qualifying
facility status of the Newark Bay Facility or any other facility under PURPA.
Sale of Capacity and Energy
We are required to arrange for capacity credits to be made available to
Public Service Electric so that Public Service Electric will be credited by PJM
with at least 123 MW of capacity per day. We must take all necessary steps for
Public Service Electric's account with PJM to reflect these 123 MW of capacity
credits per day, including utilizing PJM's "eCapacity" mechanism, throughout the
term of the amended power purchase agreement. If we are required to provide a
different quantity of capacity credits to Public Service Electric because of a
change in the measurement methodology used by PJM, the new minimum quantity of
capacity credits will be based on the operation of the Newark Bay Facility
during the 12-month period from September 1, 1998 to August 31, 1999 or a
shorter period ending August 31, 1999. If Public Service Electric's agreement
with the PJM market no longer requires Public Service Electric to obtain
capacity credits, we must provide the capacity to Public Service Electric in an
amount equal to the amount specified in the measurement methodology in effect
immediately before the cancellation of this requirement.
We will sell and deliver energy to Public Service Electric at any point on
the PJM system, and Public Service Electric must purchase this energy. The
annual energy deliveries cannot exceed 788,954 MWh for
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the years 2000 through 2002, 811,229 MWh for year 2003, 855,779 MWh for years
2004 through 2012 and 570,519 MWh for year 2013. The number of MWh that we may
schedule in the initial year of the agreement must be reduced by a pro rata
amount if the amended power purchase agreement is not in effect for the entire
calendar year of the initial year.
Purchase Price and Payment Conditions
We began receiving the payment for energy and capacity based on Public
Service Electric's delivery of energy at the contract rate of $70.74/MWh in
2000. The contract rate will increase on an annual basis as follows:
CONTRACT
YEAR RATE
- ---- --------
2001....................................................... $72.17
2002....................................................... 73.53
2003....................................................... 74.64
2004....................................................... 75.44
2005....................................................... 76.96
2006....................................................... 78.74
2007....................................................... 80.34
2008....................................................... 82.13
2009....................................................... 83.88
2010....................................................... 85.76
2011....................................................... 87.67
2012....................................................... 89.63
2013....................................................... 92.43
DELIVERY OF CAPACITY AND ENERGY
By no later than three business days prior to each calendar month, we must
provide Public Service Electric with a non-binding schedule of proposed energy
deliveries for each hour of the upcoming month. Subsequently, on the business
day preceding the day of delivery of the energy, we must provide Public Service
Electric with a final schedule for deliveries of energy by no later than one
hour prior to the time that PJM requires submission of final schedules. The
amounts set forth in the daily schedules may vary from each other and may vary
from the amounts set forth in the monthly schedule. If we fail to provide a
daily or monthly schedule to Public Service Electric, the amount of energy
scheduled for delivery will be deemed to be the amount that we set in the most
recent monthly schedule that we delivered to Public Service Electric.
We may deliver energy at a rate of up to 150 MWh per hour unless we are
also scheduling "make-up energy" (described below), in which case, we can
deliver up to 200 MWh per hour. We must schedule and deliver energy at the same
rate during all on-peak hours in any day and at the same rate during all
off-peak hours in any day. However, the delivery rate for on-peak hours in a
given day may differ from the delivery rate for off-peak hours in the same day
and the delivery rate for on-peak hours can vary from day to day.
Minimum On-Peak Deliveries
During the months of June, July, August and September, we must deliver to
Public Service Electric at least 40,000 MWh per month during the on-peak hours,
which requirement we refer to in this prospectus as the summer delivery
requirement. For all other months of the year, we must deliver an aggregate of
234,000 MWh during the on-peak hours, which requirement we refer to in this
prospectus as the yearly delivery requirement. The summer delivery requirement
and the yearly delivery requirement, together, are called the minimum energy
deliveries.
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Make-up Energy Deliveries
If a force majeure event or a system emergency prevents us from delivering,
or prevents Public Service Electric from accepting, the scheduled amount of
energy, we have the right to reschedule deliveries of make-up quantities during
comparable periods during the remainder of the month in which the inability
occurred. If we are unable to reschedule deliveries of make-up energy due to a
force majeure event or a system emergency, we have the right to reschedule the
delivery of make-up energy during comparable periods in the next month. If we
(1) fail to deliver scheduled quantities of energy or (2) fail to reschedule and
deliver in the immediately following month any make-up quantities, Public
Service Electric may permit us to reschedule any such quantities of energy in
any subsequent month.
Our Failure to Deliver Energy and Capacity
If we fail, for reasons other than a force majeure event or a system
emergency, to deliver all or part of the scheduled energy, Public Service
Electric may permit us to reschedule delivery of the energy. In the event we
fail to deliver all or part of the scheduled energy or fail to schedule
sufficient deliveries to meet the minimum energy deliveries, the payment to us
with respect to the corresponding billing period shall be reduced by a credit
against the amount payable by Public Service Electric for the next succeeding
month. If the credit amount is greater than the amount payable by Public Service
Electric for a single month, the excess portion of the credit will be applied to
reduce the amount otherwise payable by Public Service Electric for subsequent
months. Public Service Electric's credit will be calculated as follows:
- if we fail to deliver any scheduled quantities of energy, the credit will
be determined by multiplying the shortfall by the excess, if any, in the
rate that Public Service Electric had to pay to third parties to procure
energy to replace the energy that we failed to deliver over the rates
payable to us under the amended power purchase agreement;
- if we fail to schedule the summer delivery requirement for any month, the
credit will be determined by multiplying the shortfall by the excess, if
any, of the average on-peak locational marginal prices at the Newark Bay
Facility for those on-peak hours in which we failed to schedule at least
120 MW for delivery, over the rates payable to us under the amended power
purchase agreement; or
- if we fail to schedule the yearly delivery requirement, the credit will
be determined by multiplying the shortfall by the excess, if any, of the
average on-peak locational marginal prices at the Newark Bay Facility for
those on-peak hours during the non-summer months in which we failed to
schedule at least 90 MW for delivery over the rate payable to us under
the amended power purchase agreement.
If we fail for reasons other than a force majeure or a system emergency,
during any month, to provide all or part of the capacity required to be provided
to Public Service Electric, Public Service Electric must use reasonable
commercial efforts to purchase replacement capacity in the amount of the
shortfall. We must reimburse Public Service Electric for all costs associated
with the replacement. If Public Service Electric is unable to replace this
capacity shortfall, then the payments owed by Public Service Electric for that
month will be reduced by a credit against the amount payable by Public Service
Electric for the next succeeding month in an amount equal to the deficiency
charge, if any, or other charges, as applicable, payable by Public Service
Electric as a direct result of our failure to provide this capacity.
These credits are the only damages that Public Service Electric can claim
as a result of any failure by us to deliver energy or provide capacity as
required by the amended power purchase agreement. (However, the amended power
purchase agreement does not limit Public Service Electric's remedies to
liquidated damages if there is an event of default by us.)
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Damages for Failure to Accept Delivery of Energy
If Public Service Electric fails to accept deliveries of energy scheduled
by us for reasons other than a force majeure event or a system emergency, Public
Service Electric must pay us an amount equal to the positive difference between
the amount payable by Public Service Electric to us under the amended power
purchase agreement for the scheduled energy which Public Service Electric failed
to accept and the amount that we, using commercially reasonable efforts under
the circumstances, realize through remarketing that energy to persons other than
Public Service Electric.
Transmission
We are responsible for arranging transmission of all energy and capacity to
Public Service Electric and paying for all related transmission charges and
congestion costs to any delivery point. We may choose any delivery point on the
PJM system, but if we deliver energy and capacity to a delivery point other than
the Newark Bay Facility or alternate specified delivery points, the delivery
price for the energy must be reduced by an amount equal to the positive
difference between the locational marginal price at the Newark Bay Facility
interconnection point or such other specified location and the locational
marginal price at the actual delivery point.
System Emergency Exception
Public Service Electric is excused from accepting all or a portion of our
energy and capacity in the event of a system emergency if accepting our energy
and capacity would contribute to the system emergency. A "system emergency" is
defined as the existence of a physical or operational condition and/or the
occurrence of an event on Public Service Electric's system (or the PJM system)
which in Public Service Electric's judgment is imminently likely to endanger
life or property, or impairs and/or imminently will impair Public Service
Electric's ability to discharge its statutory obligation to provide safe,
adequate and proper service to its customers and/or the safety and/or
reliability of Public Service Electric's system (or PJM's system).
FORCE MAJEURE
An event of force majeure is an event beyond the reasonable control of the
party claiming force majeure. These events include, without limitation, acts of
God; strikes, lockouts or other similar industrial disturbances; acts of the
public enemy, wars, civil disturbances, blockades, military actions,
insurrections or riots; landslides, floods, washouts, lightning, earthquakes,
tornadoes, hurricanes, blizzards or other storms or storm warnings; explosions,
fires, sabotage or vandalism; mandates, directives, orders or restraints of any
governmental, regulatory or judicial body or agency (other than mandates,
directives, orders or restraints either sought, approved or not contested by the
party asserting force majeure or issued in any bankruptcy or insolvency
proceeding for the relief of the party asserting force majeure); any
catastrophic physical failures or disruptions of the PJM transmission system;
breakage, defects, malfunctioning, or accident to machinery, equipment,
materials or lines of pipe or wires; freezing of machinery, equipment, materials
or lines of pipe or wires; inability or delay in the obtaining of materials or
equipment; and inability to obtain or utilize any permit, approval, easement,
license or right-of-way.
Force majeure events do not include failures of the equipment of the party
claiming force majeure which are due to wear and tear or defects in manufacture,
design or construction; any increase in the cost of electricity supplies or
costs associated with transmission system operation, maintenance or congestion;
unavailability of capacity and/or energy from any source, regardless of price,
for delivery to a delivery point (except in the event of a system emergency);
interruption in service by a transmission provider unless the party contracting
with the transmission provider shall have made arrangements with the
transmission provider for the firm transmission, as defined under the
transmission provider's tariff, of the energy to be delivered hereunder, and the
interruption is due to an emergency or to an event of force majeure as defined
under the transmission provider's tariff; and any change in economic conditions
not caused by a force majeure event.
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If either party is rendered unable, wholly or in part, by an event of force
majeure, to perform any obligation it has under the amended power purchase
agreement, that party's obligations will be suspended to the extent those
obligations are affected by the event of force majeure for the duration of the
event of force majeure. Neither party is relieved from any obligation to make
any payment to the other during an event of force majeure. The affected party
must use its best efforts to remedy the cause of the force majeure with all
reasonable dispatch.
Neither party will be liable to the other for any claim(s), loss(es),
damage(s), liability(ies) or expense(s) sustained or incurred, arising out of,
relating to, or resulting from our or Public Service Electric's inability or
incapacity to perform its obligations under the amended power purchase agreement
due to any event of force majeure. The requirement that any event of force
majeure be remedied with all reasonable dispatch will not require the settlement
of strikes, lockouts or other similar industrial disturbances when this course
is, in the opinion of the party directly affected, inadvisable.
LIABILITY
Neither Public Service Electric nor we (including each party's officers,
directors, partners, agents, servants, employees, affiliates, parent,
subsidiaries, or successors or assigns) will be liable to the other for claims
of incidental, special, direct, indirect or consequential damages, whether the
claim is based on warranty, negligence, strict liability, contract, operation of
law or otherwise, except where the claim arises out of the gross negligence of a
party or the willful disregard by a party of its obligations under the amended
power purchase agreement. However, Public Service Electric and we each have the
right to seek to recover from the other party direct damages upon the occurrence
of an event of default under the amended power purchase agreement.
INDEMNIFICATION & WARRANTIES
We and Public Service Electric have each agreed to indemnify and hold
harmless the other (including officers, agents, servants and employees,
successors and assigns) from and against any and all claims, demands and suits,
actions, and liabilities, losses, damages, and/or judgments which may arise
therefrom as well as against any fees, costs, charges or expenses which Public
Service Electric or we, our respective officers, agents, servants and employees,
successors and assigns, incur in the defense of any such claims, suits, actions
or similar such demands made or filed by any third-party, which in any matter
arise out of, relate to, or result from negligence, or strict liability of, or
breach of the amended power purchase agreement by, the other party.
We are obligated to supply to the delivery points energy and capacity free
and clear of any liens and/or adverse claims which might attach to this energy
and capacity prior to supply and receipt by Public Service Electric except with
respect to any lien possessed by a lender. We agree to indemnify and hold
harmless Public Service Electric against any and all claims, demands, suits,
actions, costs, liabilities, damages, losses and/or judgments arising out of,
relating to or resulting from any such adverse claim or lien, as well as against
any fees, costs, charges or expenses which Public Service Electric might incur
in the defense of any such claim, suit, action or similar demand made or filed
by the claimant, or its successors or assigns, asserting the adverse claim.
DEFAULTS
Each of the following would constitute an "event of default" for us:
- We breach or fail to observe or perform any of the material obligations,
covenants, conditions, services or responsibilities under the amended
power purchase agreement, unless, within 30 days after written notice
from Public Service Electric specifying the nature of the breach or
failure, we either cure the breach or failure or, if the cure cannot be
completed within 30 days, provide Public Service Electric with a plan
reasonably acceptable to Public Service Electric to cure the breach or
failure and commence and diligently pursue the plan.
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- There is an assignment for the benefit of our creditors, or we are
adjudged a bankrupt, or a petition is filed by or against us under the
provisions of any state insolvency law or under the provisions of the
federal bankruptcy laws, or our business or principal assets are placed
in the hands of a receiver, assignee or trustee, or we are dissolved, or
our existence is terminated, or our business is discontinued. However,
these events will not constitute an event of default or otherwise affect
the validity of the amended power purchase agreement, so long as the
terms, covenants and conditions of the amended power purchase agreement
on our part are performed.
- We take any actions which prevent Public Service Electric from performing
any of its material obligations, covenants, conditions, responsibilities
or services under the amended power purchase agreement, unless, within 30
days after written notice from Public Service Electric specifying the
nature of the action or failure to act, we either cure the action or
failure to act, or, if the cure cannot be completed within 30 days,
provide Public Service Electric with a plan reasonably acceptable to
Public Service Electric to cure the breach or failure and commence and
diligently pursue the cure.
- We fail to deliver energy and capacity to Public Service Electric for 240
out of 365 days for any reason other than force majeure or a system
emergency and fail to pay the liquidated damages associated with the
failure when due or other liquidated damages payments required to be paid
under the amended power purchase agreement.
Each of the following would constitute an "event of default" for Public
Service Electric:
- Public Service Electric breaches or fails to observe or perform any of
the material obligations, covenants, conditions, services or
responsibilities under the amended power purchase agreement, unless,
within 30 days after written notice from us specifying the nature of the
breach or failure, Public Service Electric either cures the breach or
failure, or, if the cure cannot be completed within 30 days, provides us
with a plan reasonably acceptable to us to cure the breach or failure and
commences and diligently pursues the cure.
- Public Service Electric fails to accept deliveries of energy and capacity
for any reason other than a force majeure event or a system emergency,
and the failure continues for a period of 30 days following receipt of
notice of the failure and fails to pay the liquidated damages associated
with the failure as set forth in the amended power purchase agreement.
- There is an assignment for the benefit of Public Service Electric's
creditors, or Public Service Electric is adjudged bankrupt, or a petition
is filed by or against Public Service Electric under the provisions of
any state insolvency law or under the provisions of the federal
bankruptcy law, or the business or principal assets of Public Service
Electric are placed in the hands of a receiver, assignee or trustee, or
Public Service Electric is dissolved, or its existence is terminated, or
its business is discontinued. However, these events will not constitute
an event of default or otherwise affect the validity of the amended power
purchase agreement, so long as the payment for energy and capacity
delivered by us to Public Service Electric as provided under the amended
power purchase agreement continues to be made and the other terms,
covenants and conditions of the amended power purchase agreement on the
part of Public Service Electric are performed.
- Public Service Electric takes any actions which prevent us from
performing any of our material obligations, covenants, conditions,
responsibilities or services under the amended power purchase agreement,
unless within 30 days after written notice from us specifying the nature
of the action or failure to act, Public Service Electric either cures the
action or failure to act, or, if such cure cannot be completed within 30
days, provides us with a plan reasonably acceptable to us to cure the
breach or failure and commences and diligently pursues the cure.
- Public Service Electric fails to pay, when due, the payment under the
amended power purchase agreement, and the failure continues for a period
of 30 days following the receipt by Public Service Electric of notice of
the failure; provided, however, Public Service Electric shall not be
considered
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in default if (1) it has paid the undisputed portion of any payment due
under the amended power purchase agreement and (2) the parties are in the
process of resolving expeditiously any disputed portion in accordance
with the terms set forth in the amended power purchase agreement.
REMEDIES
If either party claims that an event of default has occurred, that party
must provide the other party with a written notice of breach. The parties have
30 days from the date of notice to negotiate a resolution. If the parties are
unable to resolve the dispute by negotiation, each party has the right to submit
the dispute to arbitration or any regulatory body having jurisdiction.
Both parties have the obligation to act in a commercially reasonable manner
to mitigate damages as a result of any event of default. Neither party may
refuse to make, suspend or delay any payment otherwise required under the
amended power purchase agreement or refuse to carry out any of its obligations
under the amended power purchase agreement on account of an alleged breach of
the amended power purchase agreement or event of default.
ARBITRATION AND GOVERNING LAW
Any controversy, dispute or claim between Public Service Electric and us
which is not resolved by negotiation and over which no regulatory body has
jurisdiction, or for which the regulatory body with jurisdiction declines to
initiate proceedings, shall be settled by arbitration in accordance with the
Commercial Arbitration Rules of the American Arbitration Association. Any
controversy, dispute or claim submitted to arbitration shall be settled by
arbitration in Newark, New Jersey in accordance with the laws of the State of
New Jersey.
ASSIGNMENT
We may assign our rights and obligations under the amended power purchase
agreement to El Paso Merchant or any entity controlling, controlled by or under
common control with El Paso Merchant or which has a credit rating at least equal
to Baa3 from Moody's or BBB- from Standard & Poor's or a similar rating from any
other similar independent rating agency. We may not assign our rights and
obligations under the amended power purchase agreement in any other situation
without the prior written consent of Public Service Electric, which consent will
not be unreasonably withheld.
Public Service Electric may, on notice to us, assign and transfer its
rights and obligations to any entity controlling, controlled by or under common
control with Public Service Electric and which has a credit rating by Moody's
and Standard & Poor's at least equivalent to that of Public Service Electric.
Public Service Electric may not assign its rights and/or obligations under the
amended power purchase agreement in any other situation without our prior
written consent, which consent may not be unreasonably withheld.
POWER SERVICES AGREEMENT
We entered into the power services agreement with El Paso Merchant on
September 20, 2000. Under the power services agreement, El Paso Merchant agrees
to sell us capacity and energy.
TERM
The term of the power services agreement runs from September 26, 2000 until
August 31, 2013. We or El Paso Merchant have the right to terminate the power
services agreement upon 10 days written notice if any amount due to El Paso
Merchant is not paid within 30 days after El Paso Merchant has given us notice
of the payment default; provided that El Paso Merchant will not have the right
to terminate if the reason for the non-payment results directly or indirectly
from El Paso Merchant's failure to perform under the power services agreement.
We and El Paso Merchant also have the right to terminate the power services
agreement if we terminate the amended power purchase agreement because of a
default by Public Service Electric.
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PURCHASE AND SALE OF CAPACITY AND ENERGY
General Condition of Delivery and Acceptance of Energy and Capacity
El Paso Merchant may provide energy and capacity to us at its option from
any source of supply in the PJM market, including, but not limited to, the
Newark Bay Facility.
Qualifying Facility Status
Our obligations and El Paso Merchant's obligations under the power services
agreement to buy and sell capacity and energy are not conditioned in the power
services agreement upon El Paso Merchant's maintenance of qualifying facility
status of the Newark Bay Facility or any other facility.
Distribution Surcharges
El Paso Merchant will pay to us the amount of any distribution surcharges
claimed by Public Service Electric pursuant to Article II(E) of the amended
power purchase agreement within two days of receipt of written notice from us
stating the amount of these distribution surcharges.
Sale of Capacity and Energy
El Paso Merchant must take all necessary steps for our account with PJM to
reflect 123 MW of capacity credits per day, including utilizing PJM's
"eCapacity" mechanism throughout the term of the power services agreement. If we
require a different quantity of capacity credits because of a change in the
measurement methodology used by PJM, El Paso Merchant will be required to
provide to us a new minimum quantity of capacity credits which will be based on
the operation of the Newark Bay Facility during the 12 months period from
September 1, 1998 to August 31, 1999 or any shorter period ending as of August
31, 1999, as may be appropriate under the circumstances. If the amended power
purchase agreement no longer requires us to obtain capacity credits, El Paso
Merchant shall provide capacity to us in an amount equal to the amount specified
in the measurement methodology in effect immediately prior to the cancellation
of this requirement.
El Paso Merchant must sell and deliver energy to us that is scheduled and
delivered by El Paso Merchant at any delivery point selected by us, and we must
purchase the energy at that point. The amount of the annual energy deliveries
which El Paso Merchant must schedule and deliver is 788,954 MWh for years 2000
through 2002, 811,229 MWh for year 2003, 855,779 MWh for years 2004 through 2012
and 570,519 MWh for year 2013. The number of MWh that El Paso Merchant may
schedule in the initial year of the agreement must be reduced on a pro rata
basis if the power services agreement is not in effect for the entire calendar
year.
El Paso Merchant is obligated to perform all of our obligations under the
amended power purchase agreement (including, without limitation, our obligations
to provide capacity and energy) in accordance with the terms of the amended
power purchase agreement.
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Purchase Price and Payment Conditions
El Paso Merchant is entitled to be paid for energy and capacity based on
its delivery of energy at the contract rate of $23.03/MWh in 2000. The contract
rate will change on an annual basis as follows:
CONTRACT
YEAR RATE($)
- ---- --------
2001....................................................... 29.71
2002....................................................... 29.30
2003....................................................... 28.56
2004....................................................... 27.94
2005....................................................... 28.07
2006....................................................... 28.26
2007....................................................... 28.26
2008....................................................... 28.80
2009....................................................... 29.08
2010....................................................... 29.36
2011....................................................... 29.64
2012....................................................... 29.64
2013....................................................... 33.75
DELIVERY OF CAPACITY AND ENERGY
By no later than seven business days prior to each calendar month, El Paso
Merchant must provide us with a non-binding schedule of proposed energy
deliveries for each hour of the upcoming month. Subsequently, on the business
day preceding the day of delivery of energy, El Paso Merchant must provide us
with a final schedule for deliveries of energy by no later than two hours prior
to the time that PJM requires submission of final schedules. The volumes set
forth in the daily schedules may vary from each other and may vary from the
volumes set forth in the monthly schedule. If El Paso Merchant fails to provide
a daily or monthly schedule to us, the amount of energy scheduled for delivery
will be deemed to be the amount that was set forth in the most recent monthly
schedule delivered by El Paso Merchant to us.
El Paso Merchant may deliver energy at a rate of up to 150 MWh per hour,
unless it is also scheduling make-up energy (as provided below), in which case,
up to 200 MWh per hour may be scheduled for delivery to us. El Paso Merchant
must schedule and deliver energy at the same delivery rate during all on-peak
hours in any day and at the same delivery rate during all off-peak hours in any
day. However, the delivery rate for on-peak hours in a given day may differ from
the delivery rate for off-peak hours in that day and, further, the delivery rate
for on-peak hours can vary from day to day.
We have designated El Paso Merchant to be our agent in order to perform the
scheduling obligations under the power services agreement. As our agent for
these scheduling obligations, El Paso Merchant is authorized to act in its own
name or in our name, as El Paso Merchant deems necessary or advisable.
Minimum On-Peak Deliveries
During the months of June, July, August and September, El Paso Merchant
must schedule and deliver to us a minimum of 40,000 MWh per month during the
on-peak hours. For all other months of the year, El Paso Merchant must schedule
and deliver to us an aggregate of 234,000 MWh during the on-peak hours.
Make-up Energy Deliveries
If El Paso Merchant is unable to deliver energy or if we are unable to
accept a scheduled delivery of energy due to a force majeure event or a system
emergency, El Paso Merchant must reschedule deliveries of make-up quantities of
energy during comparable periods during the remainder of the month in which
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the event or emergency occurred and El Paso Merchant must deliver the make-up
energy as rescheduled. If El Paso Merchant is unable to deliver energy or we are
unable to accept delivery as rescheduled, El Paso Merchant must reschedule
deliveries of make-up quantities of such undelivered energy during the remainder
of the month in which such inability occurred. If El Paso Merchant is unable to
reschedule such energy due to a force majeure event or a system emergency, El
Paso Merchant shall be obligated to reschedule the make-up quantities during
comparable periods in the following month. To the extent El Paso Merchant (1)
fails to deliver scheduled quantities of energy or (2) fails to deliver in the
immediately following month any such rescheduled make-up quantities, if we are
permitted under the amended power purchase agreement to reschedule and deliver
these make-up quantities in any subsequent month, then El Paso Merchant must
reschedule and deliver these make-up energy quantities in that subsequent month.
Seller's Failure to Schedule and Deliver Energy and Capacity
If El Paso Merchant fails, for reasons other than a force majeure event or
a system emergency, to deliver all or part of the scheduled energy to the
delivery point, and Public Service Electric permits us to reschedule delivery of
that energy, El Paso Merchant must reschedule the delivery of that energy at
comparable times during subsequent months. If El Paso Merchant fails to deliver
all or part of the energy scheduled for delivery, the payment to El Paso
Merchant with respect to the corresponding billing period shall be reduced by a
credit against the amount payable by us. If the credit amount is greater than
the amount payable by us for a single month, El Paso Merchant will pay us the
excess portion of the credit. That credit shall be calculated in the same manner
as the credit due to Public Service Electric under the amended power purchase
agreement and shall be applied under the power services agreement in the same
months in which the credit is applied under the amended power purchase
agreement.
If El Paso Merchant fails, for reasons other than a force majeure event or
a system emergency, during any month to provide all or part of the capacity, and
we must consequently reimburse Public Service Electric for any costs it incurred
in obtaining replacement capacity, the payments owed by us for that month shall
be reduced by a credit against the amount payable by us for the next succeeding
month in an amount equal to the deficiency charge, if any, or other charges, as
applicable, payable by Public Service Electric as a direct result of our failure
to provide such capacity under the amended power purchase agreement. If the
credit amount is greater than the amount payable by us for a single month, El
Paso Merchant will pay us the excess portion of the credit.
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Shortfall Payments
If El Paso Merchant does not deliver the annual energy deliveries in any
year, El Paso Merchant must pay us an amount equal to (1) the difference between
the annual energy deliveries for the relevant year and the energy actually
delivered by El Paso Merchant during that year multiplied by (2) the difference
between the liquidated damages rate for that calendar year and the contract
rate, as set forth in the power services agreement, for that calendar year. The
liquidated damages rate under the power services agreement for each year
beginning with 2000 is set forth below. El Paso Merchant must pay these
shortfall payments within five days after receipt of the invoice from us. We
must provide this invoice on or before the fifth day of February of the
succeeding calendar year.
LIQUIDATED
YEAR DAMAGES RATE
- ---- ------------
2000................................................... $70.74
2001................................................... 72.17
2002................................................... 73.53
2003................................................... 74.64
2004................................................... 75.44
2005................................................... 76.96
2006................................................... 78.74
2007................................................... 80.34
2008................................................... 82.13
2009................................................... 83.88
2010................................................... 85.76
2011................................................... 87.67
2012................................................... 89.63
2013................................................... 92.43
Transmission
El Paso Merchant is responsible for arranging transmission of all energy
and capacity to us and paying for all related transmission charges and
congestion costs to the delivery point. If El Paso Merchant elects to deliver
energy and capacity to a delivery point other than the Newark Bay Facility or
two alternate specified delivery points, the delivery price for the energy must
be reduced by a credit in an amount equal to the positive difference between the
locational marginal price at the Newark Bay Facility interconnection point and
the locational marginal price at the actual point of delivery; provided that, if
the amount of the credit is greater than the amount payable by us for a single
month, El Paso Merchant will pay to us an amount equal to this excess portion of
the credit.
System Emergency Exception
We are excused from accepting all or a portion of El Paso Merchant's energy
and capacity in the event of a system emergency if the purchases would
contribute to the system emergency. A system emergency is the existence of a
physical or operational condition and/or the occurrence of an event on Public
Service Electric's system or the PJM system which in Public Service Electric's
judgment is imminently likely to endanger life or property, or impairs and/or
imminently will impair Public Service Electric's ability to discharge its
statutory obligation to provide safe, adequate and proper service to its
customers and/or the safety and/or reliability of Public Service Electric's
system or PJM's system.
FORCE MAJEURE
An event of "force majeure" is an event beyond the reasonable control of
the party claiming force majeure so long as the event is deemed to be a force
majeure event under the amended power purchase agreement (whether or not the
amended power purchase agreement is in full force and effect). These events
include, without limitation, acts of God; strikes, lockouts or other similar
industrial disturbances;
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acts of the public enemy, wars, civil disturbances, blockades, military actions,
insurrections or riots; landslides, floods, washouts, lightning, earthquakes,
tornadoes, hurricanes, blizzards or other storms or storm warnings; explosions,
fires, sabotage or vandalism; mandates, directives, orders or restraints of any
governmental, regulatory or judicial body or agency (other than mandates,
directives, orders or restraints either sought, approved or not contested by the
party asserting force majeure or issued in any bankruptcy or insolvency
proceeding for the relief of the party asserting force majeure); any
catastrophic physical failures or disruptions of the PJM transmission system;
breakage, defects, malfunctioning, or accident to machinery, equipment,
materials or lines of pipe or wires; freezing of machinery, equipment, materials
or lines of pipe or wires; inability or delay in the obtaining of materials or
equipment; inability to obtain or utilize any permit, approval, easement,
license or right-of-way; and events of force majeure as defined under and
declared by either party to the amended power purchase agreement.
Force majeure events do not include failures of the equipment of the party
claiming force majeure which are due to wear and tear or defects in manufacture,
design or construction; any increase in the cost of electricity supplies or
costs associated with transmission system operation, maintenance or congestion;
unavailability of capacity and/or energy from any source, regardless of price,
for delivery to a delivery point (except in the event of a system emergency);
interruption in service by a transmission provider (unless the party claiming
force majeure has contracted with the transmission provider for firm
transmission of the energy, and the interruption is due to an emergency or to an
event of force majeure as defined under the transmission provider's tariff); and
any change in economic conditions not caused by a force majeure event.
If either El Paso Merchant or we are rendered unable, wholly or in part, by
an event of force majeure, to perform any obligation either of us has under the
power services agreement, when the party affected by the event of force majeure
gives notice describing the event to the other party, the affected party's
obligations will be suspended during the continuance of the event of force
majeure, but for no longer period. These obligations will be suspended for no
longer period than the event of force majeure has suspended the parties'
obligations under the amended power purchase agreement or in the event that the
amended power purchase agreement is no longer in full force and effect, would
have suspended the parties' obligations under the amended power purchase
agreement. Neither party will be relieved of any obligation to make any payment
to the other required under the power services agreement. The affected party
will use its best efforts to remedy the cause of the force majeure with all
reasonable dispatch. The obligations of El Paso Merchant under the power
services agreement to schedule and deliver the annual energy deliveries (other
than the minimum energy deliveries) will not be excused or suspended by an event
of force majeure.
Neither party will be liable to the other for any claims, losses, damages,
liabilities or expenses sustained or incurred, arising out of, relating to, or
resulting from El Paso Merchant's or our inability or incapacity to perform its
obligations under the power services agreement due to any event of force
majeure. The requirement that any event of force majeure will be remedied with
all reasonable dispatch will not require the settlement of strikes, lockouts or
other similar industrial disturbances when this course is, in the opinion of the
party directly affected, inadvisable.
LIABILITY
Neither of El Paso Merchant nor we (including our respective officers,
directors, partners, agents, servants, employees, affiliates, parent,
subsidiaries or successors or assigns) will be liable to the other for claims of
incidental, special, direct, indirect or consequential damages, whether the
claim is based on warranty, negligence, strict liability, contract, operation of
law or otherwise, except where the claim arises out of the gross negligence of
the claimant or the willful disregard by the claimant of its obligations under
the power services agreement. However, we have the right to seek to recover from
El Paso Merchant direct damages upon the occurrence of an event of default under
the amended power purchase agreement, and to seek indemnification payments
required to be paid by us to Public Service Electric under the amended power
purchase agreement. In the event of the termination of the amended power
purchase agreement prior to the termination of the power services agreement, El
Paso Merchant will not be liable to
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us under the power services agreement unless El Paso Merchant would have been
liable under the power services agreement if the amended power purchase
agreement were in full force and effect.
INDEMNIFICATION AND WARRANTIES
El Paso Merchant has agreed to indemnify and hold harmless us and our
officers, agents, servants and employees, our successors and assigns from and
against any and all claims, demands and suits, actions, and liabilities, losses,
damages, and/or judgments which may arise therefrom as well as against any fees,
costs, charges or expenses which we, our officers, agents, servants and
employees, our successors and assigns, incur in the defense of any such claims,
suits, actions or similar demands made or filed by any third-party, which in any
matter arise out of, relate to, or result from negligence, strict liability or a
breach of the power services agreement by El Paso Merchant and against claims,
suits, actions or similar demands made or filed by Public Service Electric
against us pursuant to the amended power purchase agreement.
El Paso Merchant is obligated to supply to the delivery points energy and
capacity free and clear of any liens and/or adverse claims which might attach to
the energy and capacity prior to its supply and receipt by us except with
respect to any lien possessed by a lender to us. El Paso Merchant agreed to
indemnify us and hold us harmless against any and all claims, demands, suits,
actions, costs, and liabilities, damages, losses and/or judgments arising out
of, relating to, or resulting from any such adverse claim or lien, as well as
against any fees, costs, charges or expenses which we might incur in the defense
of any such claim, suit, action or similar demand made or filed by the claimant,
or its successors or assigns, asserting the adverse claim.
DEFAULTS
Each of the following constitutes an "event of default" by El Paso
Merchant:
- El Paso Merchant breaches or fails to observe or perform any of the
material obligations, covenants, conditions, services or responsibilities
under the power services agreement, unless, within 25 days after written
notice from us specifying the nature of the breach or failure, El Paso
Merchant either cures the breach or failure or, if the cure cannot be
completed within 25 days, provides us with a plan reasonably acceptable
to us to cure the breach or failure and commences and diligently pursues
the plan.
- There is an assignment for the benefit of El Paso Merchant's creditors,
or El Paso Merchant is adjudged a bankrupt, or a petition is filed by or
against El Paso Merchant under the provisions of any state insolvency law
or under the provisions of the federal bankruptcy laws, or El Paso
Merchant's business or principal assets are placed in the hands of a
receiver, assignee or trustee, or El Paso Merchant is dissolved, or El
Paso Merchant's existence is terminated, or El Paso Merchant's business
is discontinued. However, these events will not constitute an event of
default or otherwise affect the validity of the power services agreement,
so long as the terms, covenants and conditions of the power services
agreement on El Paso Merchant's part are performed.
- El Paso Merchant takes any action which prevents us from performing any
of our material obligations, covenants, conditions, responsibilities or
services under the power services agreement, unless, within 25 days after
written notice from us specifying the nature of the action or failure to
act, El Paso Merchant either cures the action or failure to act, or, if
the cure cannot be completed within 25 days, provides us with a plan
reasonably acceptable to us to cure the breach or failure and commences
and diligently pursues the cure.
- El Paso Merchant fails to deliver energy and capacity to us for 240 out
of 365 days for any reason other than force majeure or a system emergency
and fails to pay the liquidated damages associated with the failure when
due or other liquidated damages payments required to be paid under the
power services agreement.
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REMEDIES
If we claim that an event of default has occurred, we must provide El Paso
Merchant with a written notice of breach. The parties have 25 days from the date
of notice to negotiate a resolution. If the parties are unable to resolve the
dispute by negotiation, each party will have the right to submit the dispute to
arbitration or any regulatory body having jurisdiction, such arbitration
proceeding to be joined with any arbitration proceeding initiated under the
amended power purchase agreement with respect to substantially the same dispute
or with respect to another dispute involving substantially the same facts.
We have the obligation to act in a commercially reasonable manner to
mitigate damages as a result of any event of default. Neither party shall refuse
to make, suspend or delay any payment otherwise required under the power
services agreement or refuse to carry out any of its obligation under the power
services agreement on account of an alleged breach of the power services
agreement or event of default.
ARBITRATION AND GOVERNING LAW
Any controversy, dispute or claim between the parties to the power services
agreement which is not resolved by negotiation and over which no regulatory body
has jurisdiction or, having jurisdiction, declines to initiate proceedings will
be settled by arbitration in accordance with the Commercial Arbitration Rules of
the American Arbitration Association. Any controversy, dispute or claim
submitted to arbitration will be settled by arbitration in Newark, New Jersey in
accordance with the laws of the State of New Jersey.
We and El Paso Merchant have agreed that, in the event a dispute arises
under the power services agreement and separate arbitration proceedings are
initiated under the power services agreement and under Article XV of the amended
power purchase agreement with respect to substantially the same dispute or with
respect to another dispute involving substantially the same facts, these
disputes will be resolved jointly in a single proceeding by the arbitration
proceedings initiated under Article XV of the amended power purchase agreement.
ASSIGNMENT
We may assign our rights in the power services agreement to any lender
(including a trustee on behalf of the holders) in connection with any financing
or other financial arrangement or to any person succeeding to all or
substantially all of our assets without El Paso Merchant's consent. For any
other reasons, we may not assign our rights and obligations under the power
services agreement to any person without El Paso Merchant's prior written
consent, which shall not be unreasonably delayed or withheld so long as the
assignee agrees to be bound by, subject to and to comply with the terms and
conditions of the power services agreement. El Paso Merchant may not assign its
rights and obligations under the power services agreement without our prior
written consent.
ADMINISTRATIVE SERVICES AGREEMENT
We entered into the administrative services agreement with El Paso Merchant
on September 20, 2000. Under the administrative services agreement, El Paso
Merchant has agreed to perform all administrative and managerial functions to be
performed by us pursuant to our material agreements, the indenture and the
related financing documents.
TERM
The term of the administrative services agreement commenced upon execution
and runs until the expiration or earlier termination of the power services
agreement. Neither our nor El Paso Merchant's rights and obligations under the
administrative services agreement commence, however, until the effective date of
the amended power purchase agreement. We have the right to terminate the
administrative services agreement (1) at any time on 60 days written notice to
El Paso Merchant and the payment to El Paso Merchant of any amounts owed El Paso
Merchant under the administrative services agreement or (2) upon El Paso
Merchant's bankruptcy, insolvency or liquidation.
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SUPPORT OBLIGATIONS
Management and Administrative Services
El Paso Merchant must perform the following management and administrative
services: accounting, auditing, financial reporting, budgeting and forecasting,
tax, cash management, review of significant operating and financial matters,
contract administrative services, invoicing, setting off amounts as permitted
under the power services agreement, computer and information services, and such
other management, administrative, and regulatory filing services as directed by
us. Specifically, El Paso Merchant must provide the following services:
- maintaining our books and records in accordance with good business
practice, Internal Revenue Service regulations, applicable law and
generally accepted accounting principles and the retention and oversight
of independent auditors to review these books and records on an annual
basis;
- providing services regarding our cash, including (1) establishing bank
accounts and (2) investing funds in accordance with the financing
documents;
- providing accounting services related to the development and
implementation of our financial controls and systems and the
administering of the financing proceeds;
- exercising all of our rights and performing all of our administrative and
management obligations under the financing documents, including taking
all actions necessary to perfect and maintain the perfection and priority
of any security interests granted by us to any lender or creditor of ours
over any of our assets;
- administering the amended power purchase agreement, the power services
agreement and the other material agreements, and exercising all of our
rights and performing all of our obligations thereunder;
- to the extent that amounts are available from us, paying all of our fees,
debts and obligations;
- providing tax related services, including, without limitation, paying
from El Paso Merchant's accounts directly to any third party payees, upon
demand, any taxes or other administrative fees and expenses due and
payable by us;
- making and prosecuting, or causing to be made and prosecuted, such
filings and reports, keeping such records, and taking or causing to be
taken such other actions as may be necessary and lawful to maintain our
existence and good standing and to ensure our compliance with all
applicable laws, regulations, authorizations and orders of any government
agencies (including, without limitation, the Federal Energy Regulatory
Commission); and
- doing and performing such other acts as may be mutually agreed to by El
Paso Merchant and us from time to time.
ASSIGNMENT
We may assign our rights in the administrative services agreement to any
lender (including a trustee on behalf of the holders) in connection with any
financing or other financial arrangement or to any person succeeding to all or
substantially all of our assets without El Paso Merchant's consent. For any
other reasons, we may not assign our rights and obligations under the
administrative services agreement to any person without El Paso Merchant's prior
written consent, which shall not be unreasonably delayed or withheld so long as
the assignee agrees to be bound by, subject to and to comply with the terms and
conditions of the administrative services agreement. El Paso Merchant may not
assign its rights and obligations under the administrative services agreement
without our prior written consent.
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FEE
We will pay El Paso Merchant $50,000 on February 15 and August 15 of each
year under the administrative services agreement. This amount will cover all of
El Paso Merchant's internal and overhead costs. We will reimburse El Paso
Merchant for all expenses other than internal and overhead costs El Paso
Merchant incurs in performing its obligations under the administrative services
agreement on February 15 and August 15 of each year following El Paso Merchant's
delivery of an invoice not less than 30 days prior to each of these dates. The
fees and expenses to El Paso Merchant under the administrative services
agreement will be due and payable only to the extent that there are amounts on
deposit in the collections account after payment in accordance with the
indenture of all current and past due amounts ranking prior to the payment of
these fees and expenses.
DEFAULTS
Each of the following constitutes an "event of default" with respect to
either El Paso Merchant or us under the administrative services agreement:
- failure to make, when due, any payment under the administrative services
agreement if the failure is not remedied within 10 business days of
written notice of the failure by the non-defaulting party;
- any representation or warranty made by a party is false or misleading in
any material respect when made; or
- failure by a party to perform any material covenant set forth in the
administrative services agreement.
Upon an event of default, the non-defaulting party has the right to
terminate the administrative services agreement.
EL PASO PERFORMANCE GUARANTY
We entered into the El Paso performance guaranty with El Paso on September
20, 2000. Under the El Paso performance guaranty, El Paso guarantees to us the
punctual performance of all of El Paso Merchant's obligations under the power
services agreement and the administrative services agreement.
TERM
The term of the El Paso performance guaranty runs from the date of
execution until all of El Paso Merchant's obligations under the power services
agreement and the administrative services agreement have been performed. The El
Paso performance guaranty will remain in full force and effect or be reinstated
if at any time any payment by El Paso Merchant in whole or in part is rescinded
or must otherwise be returned by us upon El Paso Merchant's insolvency,
bankruptcy or reorganization.
GUARANTY
El Paso irrevocably and unconditionally guarantees to us the punctual
performance and payment of all of El Paso Merchant's obligations under the power
services agreement and the administrative services agreement.
El Paso will perform its guaranty in full irrespective of any claim,
set-off, or other right it may have at any time against us, El Paso Merchant or
any other entity. The guaranty is a primary obligation of El Paso and El Paso
will perform its guaranty regardless of the validity or enforceability of the
power services agreement or the administrative services agreement, any changes
to the power services agreement or the administrative services agreement, or any
other circumstances constituting a legal or equitable discharge or defense of a
guarantor.
All payments that El Paso is required to make under the El Paso performance
guaranty are without any set-off, counterclaim or condition. The guaranty is not
affected by El Paso Merchant's change of
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ownership, insolvency, bankruptcy or any other change in El Paso Merchant's
legal status. If El Paso Merchant's obligations are stayed or performance is
delayed upon insolvency, bankruptcy or reorganization, El Paso's guaranty will
remain in full force and effect and will be immediately due to the extent
required absent the stay or delay.
WAIVERS
El Paso irrevocably waives diligence, promptness, presentment, demand for
payment or performance, protest, and notice of any kind with respect to all of
its obligations. El Paso also waives any legal or equitable defenses arising out
of El Paso Merchant's insolvency, bankruptcy or similar legal disability.
COVENANTS
El Paso will not exercise any right of subrogation or indemnity, or similar
right or remedy, against El Paso Merchant or any of El Paso Merchant's assets or
property in respect of any amount it paid under the El Paso performance guaranty
or file a proof of claim in competition with us for any amount owed by El Paso
Merchant to El Paso on any account whatsoever in the event of insolvency or
bankruptcy, until all of El Paso Merchant's obligations under the administrative
services agreement and power services agreement are performed. El Paso covenants
that the El Paso performance guaranty will not be discharged except by complete
and final payment and performance of El Paso Merchant's obligations under the
power services agreement and administrative services agreement and by El Paso
under the El Paso performance guaranty.
DEFAULTS
Each of the following would constitute an "event of default" for El Paso:
- El Paso's failure to make or perform, when due, any payment or
performance required to be made under the El Paso performance guaranty;
- any representation or warranty made by El Paso proves to be false or
misleading in any material respect when made; and
- bankruptcy, insolvency or liquidation of El Paso.
REMEDY
The rights and remedies set forth in the El Paso performance guaranty are
in addition to and not exclusive of any rights and remedies available to us. If
any amount payable by El Paso is not paid to us under the El Paso performance
guaranty when due, we may, without notice or demand of any kind, set-off and
apply the unpaid amount against any amounts then due and payable by us to El
Paso or El Paso Merchant.
EXPENSES
El Paso will reimburse us on demand for all reasonable costs and expenses
including attorney's fees we incur in connection with the enforcement of our
rights under the El Paso performance guaranty.
ASSIGNMENT
The El Paso performance guaranty is binding on El Paso and its successors
and assigns. El Paso may not transfer any of its obligations under the El Paso
performance guaranty without the prior written consent by us.
We may transfer, pledge, encumber or assign the El Paso performance
guaranty or the accounts, revenues or proceeds under the El Paso performance
guaranty without El Paso's consent in connection with any financing and may
transfer or assign the El Paso performance guaranty to any entity succeeding to
all or substantially all of our assets.
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RELATIONSHIPS WITH AFFILIATES AND RELATED TRANSACTIONS
El Paso Merchant and El Paso are affiliates of each other and an affiliate
of each of them manages us. All of the individuals who perform the day-to-day
financial, administrative, accounting and operational functions for us, as well
as those who are responsible for our direction, are currently employed by El
Paso Merchant. Under the administrative services agreement, El Paso Merchant is
paid a fee of $50,000 semi-annually. See "Summary of Our Transaction
Documents -- Administrative Services Agreement." Pursuant to the power services
agreement, El Paso Merchant provides reserved capacity and delivers energy on
the terms and at the rates set forth in that agreement. See "Summary of Our
Transaction Documents -- Power Services Agreement." We believe that the terms of
the administrative services agreement and the power services agreement are
commercially reasonable and contain terms that are at least as favorable to us
as we would expect to negotiate with unaffiliated third parties.
THE EXCHANGE OFFER
EXCHANGE TERMS
Series A bonds with a principal amount of $310,600,000 are currently issued
and outstanding. The maximum principal amount of Series B bonds that will be
issued in exchange for Series A bonds is $310,600,000. The terms of the Series B
bonds and the Series A bonds are substantially the same in all material
respects, except that the Series B bonds will be freely transferable by the
holders except as provided in this prospectus.
The Series B bonds will bear interest at a rate of 8 1/2% per year, payable
semi-annually on February 15 and August 15 of each year, beginning on February
15, 2001. Holders of Series B bonds will receive interest from the date of the
original issuance of the Series A bonds or from the date of the last payment of
interest on the Series A bonds, whichever is later. Holders of Series B bonds
will not receive any interest on Series A bonds tendered and accepted for
exchange. In order to exchange your Series A bonds for transferable Series B
bonds in the exchange offer, you will be required to make the following
representations, which are included in the letter of transmittal:
- any Series B bonds 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 Series B
bonds;
- you are not our "affiliate," as defined in Rule 405 of the Securities
Act, or a broker-dealer tendering Series A bonds acquired directly from
us; 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 Series B bonds.
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 Series A bonds
properly tendered in the exchange offer, and the exchange agent will deliver the
Series B bonds promptly after the expiration date of the exchange offer.
If you tender your Series A bonds, 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 Series A bonds
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 SERIES A BONDS 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 SERIES A BONDS TO TENDER
AFTER READING THIS PROSPECTUS
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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 [ ],
2001, 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 Series A bonds for exchange;
- to terminate the exchange offer if any of the conditions set forth under
"-- Conditions of the Exchange Offer" beginning on page 66 exist;
- to waive any condition to the exchange offer;
- to amend any of the terms of the exchange offer; and
- to extend the expiration date and retain all Series A bonds tendered in
the exchange offer, subject to your right to withdraw your tendered
Series A bonds as described under "-- Withdrawal of Tenders."
Any waiver or amendment to the exchange offer will apply to all Series A
bonds tendered, regardless of when or in what order the Series A bonds 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 Series A
bonds, 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 Series A bonds 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, Series B bonds will not be given to holders of Series A bonds who
have validly tendered their Series A bonds.
RESALE OF SERIES B BONDS
Based on interpretations of the SEC staff set forth in no action letters
issued to third parties, we believe that Series B bonds issued under the
exchange offer in exchange for Series A bonds 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 not our "affiliate" within the meaning of Rule 405 under the
Securities Act;
- you are not participating, and have no arrangement or understanding with
any person to participate, in the distribution of the Series B bonds;
- you are not a broker-dealer who purchased Series A bonds directly from us
for resale pursuant to Rule 144A or any other available exemption under
the Securities Act; and
- you are acquiring Series B bonds in the ordinary course of your business.
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If you tender Series A bonds in the exchange offer with the intention of
participating in any manner in a distribution of the Series B bonds:
- 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 Series A bonds as a result of
market-making activities or other trading activities may participate in the
exchange offer. Each broker-dealer that receives Series B bonds for its own
account in exchange for Series A bonds, where such Series A bonds 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 Series B bonds. Please read the section captioned "Plan
of Distribution" beginning on page 93 for more details regarding the transfer of
Series B bonds.
ACCEPTANCE OF SERIES A BONDS FOR EXCHANGE
We will accept for exchange Series A bonds validly tendered pursuant to the
exchange offer, or defectively tendered, if such defect has been waived by us,
after the later of: (1) the expiration date of the exchange offer and (2) the
satisfaction or waiver of the conditions specified below under "Conditions of
the Exchange Offer." We will not accept Series A bonds for exchange subsequent
to the expiration date of the exchange offer. Tenders of Series A bonds will be
accepted only in minimum denominations equal to $100,000 or integral multiples
of $1,000 in excess thereof.
We expressly reserve the right, in our sole discretion, to:
- delay acceptance for exchange of Series A bonds 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 Series A
bonds 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, Series B bonds will be issued only
after timely receipt by the exchange agent of certificates representing
Series A bonds, 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 Series A bonds, or defectively tendered Series A bonds 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 Series B bonds
with the exchange agent, who will act as agent for the tendering holders
for the purpose of receiving the Series B bonds and transmitting them to
the holders. The exchange agent will deliver the Series B bonds to
holders of Series A bonds accepted for exchange after the exchange agent
receives the Series B bonds.
If, for any reason, we delay acceptance for exchange of validly tendered
Series A bonds or we are unable to accept for exchange validly tendered Series A
bonds, then the exchange agent may, nevertheless, on our behalf, retain tendered
Series A bonds, without prejudice to our rights described under "-- Expiration
Date; Extensions; Termination; Amendments" beginning on page 61, "-- Conditions
of the Exchange Offer" beginning on page 66 and "-- Withdrawal of Tenders"
beginning on page 66, subject to Rule 14e-1 under the Exchange Act, which
requires that an offeror pay the consideration offered or return
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the securities deposited by or on behalf of the holders thereof promptly after
the termination or withdrawal of a tender offer.
If any tendered Series A bonds are not accepted for exchange for any
reason, or if certificates are submitted evidencing more Series A bonds than
those that are tendered, certificates evidencing Series A bonds that are not
exchanged will be returned, without expense, to the tendering holder, or, in the
case of Series A bonds 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 Series A Bonds -- Book-Entry Transfer" beginning on
page 64, such Series A bonds will be credited to the account maintained at such
book-entry transfer facility from which such Series A bonds were delivered,
unless otherwise requested by such holder under "Special Delivery Instructions"
in the letter of transmittal, promptly following the exchange date or the
termination of the exchange offer.
Tendering holders of Series A bonds exchanged in the exchange offer will
not be obligated to pay brokerage commissions or transfer taxes with respect to
the exchange of their Series A bonds other than as described in "Transfer Taxes"
beginning on page 67 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 SERIES A BONDS
Any beneficial owner whose Series A bonds 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 Series A bonds should
contact such registered holder promptly and instruct such registered holder to
tender Series A bonds on such beneficial owner's behalf.
Tender of Series A Bonds Held Through Depository Trust
The exchange agent and Depository Trust have confirmed that the exchange
offer is eligible for the Depository Trust automated tender offer program.
Accordingly, Depository Trust participants may electronically transmit their
acceptance of the exchange offer by causing Depository Trust to transfer Series
A bonds to the exchange agent in accordance with Depository Trust's automated
tender offer program procedures for transfer. Depository Trust will then send an
agent's message to the exchange agent.
The term "agent's message" means a message transmitted by Depository Trust,
received by the exchange agent and forming part of the book-entry confirmation,
which states that Depository Trust has received an express acknowledgment from
the participant in Depository Trust tendering Series A bonds 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
Depository Trust and received by the exchange agent which states that Depository
Trust has received an express acknowledgment from the participant in Depository
Trust tendering Series A bonds that they have received and agree to be bound by
the notice of guaranteed delivery.
Tender of Series A Bonds Held in Certificated Form
For a holder to validly tender Series A bonds 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 Series A bonds
at such address, or such Series A bonds must be transferred pursuant to
the procedures for book-entry transfer described above. 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
Series A bonds and who cannot comply with the procedures set forth herein
for tender on a timely basis or whose Series A
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bonds are not immediately available must comply with the procedures for
guaranteed delivery set forth below.
LETTERS OF TRANSMITTAL AND SERIES A BONDS SHOULD BE SENT ONLY TO THE
EXCHANGE AGENT, AND NOT TO US OR TO ANY BOOK-ENTRY TRANSFER FACILITY.
THE METHOD OF DELIVERY OF SERIES A BONDS, LETTERS OF TRANSMITTAL AND ALL
OTHER REQUIRED DOCUMENTS TO THE EXCHANGE AGENT IS AT THE ELECTION AND RISK OF
THE HOLDER TENDERING SERIES A BONDS. 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 PROPERTY 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
SERIES A BONDS 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
Series A bonds 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 Series A bonds, or if any Series A bonds
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 Series A bonds 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 neither
the "Special Issuance Instructions" nor the "Special Delivery
Instructions" box on the letter of transmittal has been completed, or
- the Series A bonds are tendered for the account of an eligible
institution.
An eligible institution is a firm that is a participant in the Security
Transfer Agents Medallion program or the Stock Exchange Medallion program, which
is generally a member of a registered national securities exchange, a member of
the National Association of Securities Dealers, Inc., or a commercial bank or
trust company having an office in the United States.
Book-Entry Transfer
The exchange agent will seek to establish a new account or utilize an
existing account with respect to the Series A bonds at Depository Trust promptly
after the date of this prospectus. Any financial institution that is a
participant in the book-entry transfer facility system and whose name appears on
a security position listing it as the owner of the Series A bonds may make
book-entry delivery of Series A bonds by causing the book-entry transfer
facility to transfer such Series A bonds into the exchange agent's account.
HOWEVER, ALTHOUGH DELIVERY OF SERIES A BONDS MAY BE EFFECTED THROUGH BOOK-ENTRY
TRANSFER INTO THE EXCHANGE AGENT'S ACCOUNT AT A BOOK-ENTRY TRANSFER FACILITY, 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 Series A bonds
into the exchange agent's account at a book-entry transfer facility is referred
to in this prospectus as a "book-entry confirmation." Delivery of documents to
the book-entry transfer facility in accordance with that book-entry transfer
facility's procedures does not constitute delivery to the exchange agent.
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Guaranteed Delivery
If you wish to tender your Series A bonds and:
(1) certificates representing your Series A bonds are not lost but are
not immediately available,
(2) time will not permit your letter of transmittal, certificates
representing your Series A bonds 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 are complied with:
- your tender is made by or through an eligible institution;
- 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 Series A bonds and the principal amount of Series A bonds
tendered;
(b) state that the tender is being made thereby;
(c) guarantee that, within three New York Stock Exchange trading
days after the date of the notice of guaranteed delivery, the
letter of transmittal or facsimile thereof properly completed
and validly executed, together with certificates representing
the Series A bonds, 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 for
all Series A bonds 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 date of the
notice of guaranteed delivery.
Other Matters
Series B bonds will be issued in exchange for Series A bonds accepted for
exchange only after timely receipt by the exchange agent of:
- certificates for (or a timely book-entry confirmation with respect to)
your Series A bonds,
- 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 Series A bonds. Our determination will be final and binding on
all parties. ALTERNATIVE, CONDITIONAL OR CONTINGENT TENDERS OF SERIES A BONDS
WILL NOT BE CONSIDERED VALID. We reserve the absolute right to reject any or all
tenders of Series A bonds 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 Series A bonds.
Our interpretation of the terms and conditions of the exchange offer,
including the instructions in the letter of transmittal, will be final and
binding.
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Any defect or irregularity in connection with tenders of Series A bonds
must be cured within the time we determine, unless waived by us. We will not
consider the tender of Series A bonds 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 Series A bonds, 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 Series A bonds 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" on page 68, or
- you must comply with the appropriate procedures of Depository Trust's
automated tender offer program system.
Any notice of withdrawal must:
- specify the name of the person who tendered the Series A bonds to be
withdrawn and
- identify the Series A bonds to be withdrawn, including the principal
amount of the Series A bonds.
If Series A bonds 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 Depository Trust to be credited with the
withdrawn Series A bonds and otherwise comply with the procedures of Depository
Trust.
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 Series A bonds so withdrawn not to have
been validly tendered for exchange for purposes of the exchange offer.
Any Series A bonds 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 Series A bonds tendered by book-entry transfer into
the exchange agent's account at Depository Trust according to the procedures
described above, such Series A bonds will be credited to an account maintained
with Depository Trust for the Series A bonds. 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 Series A
bonds by following one of the procedures described under "-- Procedures for
Tendering Series A Bonds" beginning on page 63 at any time on or prior to the
expiration date.
CONDITIONS OF THE EXCHANGE OFFER
Notwithstanding any other provisions of the exchange offer, we will not be
required to accept for exchange, or exchange any Series B bonds for, any Series
A bonds tendered. We may terminate, waive any conditions to or amend the
exchange offer and may, 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, postpone the acceptance for exchange of
Series A bonds so tendered if, on or prior to the expiration date of the
exchange offer, we determine that the exchange offer would violate applicable
law or any applicable interpretation of the staff of the SEC.
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TRANSFER TAXES
We will pay all transfer taxes applicable to the transfer and exchange of
Series A bonds pursuant to the exchange offer. If, however:
- delivery of the Series B bonds and/or certificates for Series A bonds for
principal amounts not exchanged, are to be made to any person other than
the recordholder of the Series A bonds tendered;
- tendered certificates for Series A bonds 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 Series A bonds to us or our order,
the amount of any such transfer taxes, whether imposed on the recordholder or
any other person, will be payable by the tendering holder prior to the issuance
of the Series B bonds.
CONSEQUENCES OF EXCHANGING AND FAILING TO EXCHANGE
If you do not exchange your Series A bonds for Series B bonds in the
exchange offer, you will remain subject to the restrictions on transfer of the
Series A bonds:
- as set forth in the legend printed on the bonds as a consequence of the
issuance of the Series A bonds 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 memorandum distributed in connection with the
private offering of the Series A bonds.
In general, you may not offer or sell the Series A bonds 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 Series A bonds under the Securities Act.
Based on interpretations of the SEC staff, you may offer for resale, resell
or otherwise transfer Series B bonds issued in the exchange offer without
compliance with the registration and prospectus delivery provisions of the
Securities Act, provided that (1) you are not our "affiliate" within the meaning
of Rule 405 under the Securities Act, (2) you acquired the Series B bonds in the
ordinary course of your business and (3) you have no arrangement or
understanding with respect to the distribution of the Series B bonds to be
acquired in the exchange offer. If you are an affiliate of our company, or are
engaged in or intend to engage in, or have any arrangement with respect to, a
distribution of the Series B bonds:
- you cannot rely on the applicable interpretations of the SEC; and
- you must comply with the registration and prospectus delivery
requirements of the Securities Act in connection with a secondary resale
transaction and 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.
ACCOUNTING TREATMENT
The Series B bonds will be recorded at the same carrying value as the
Series A bonds, 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
Bankers 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 Series A
bonds, letters of transmittal and any other required documents to the exchange
agent addressed as follows:
BANKERS TRUST COMPANY
By Overnight, By Mail: By Hand in New York:
Registered or Certified Mail BT Services Tennessee, Inc. Bankers Trust Company
or Overnight Courier: Reorganization Unit Corporate Trust and Agency
BT Services Tennessee, Inc. P.O. Box 292737 Group
Corporate Trust & Agency Group Nashville, Tennessee 37229-2737 Attn: Reorganization Department
Reorganization Unit Receipt and Delivery Window
648 Grassmere Park Road 123 Washington Street-1st Floor
Nashville, Tennessee 37211 New York, New York 10006
Information: (800) 735-7777
By Facsimile:
(for eligible institutions only)
(615) 835-3701
Confirm by telephone:
(615) 835-3572
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DESCRIPTION OF THE BONDS
The following summaries of material provisions of the indenture and the
bonds do not purport to be complete and are subject to, and are qualified in
their entirety by reference to, all of the provisions of the indenture, and the
bonds, including the definitions therein. Copies of the indenture are available
for inspection at the corporate trust office of the trustee. We urge you to read
the bonds and the indenture because they, and not this description, define your
rights as holder of the bonds. Capitalized terms used herein and not otherwise
defined in this prospectus have the meanings ascribed to them under "Defined
Terms."
We issued the Series A bonds under an indenture dated September 26, 2000,
as amended by supplemental indentures dated November 20, 2000 and January 19,
2001, between us and Bankers Trust Company, as trustee, in a private transaction
that was not subject to the registration requirements of the Securities Act. The
Series B bonds will be issued under the same indenture. The terms of the bonds
include those stated in the indenture and those made part of the indenture by
reference to the Trust Indenture Act.
GENERAL
The Series A bonds and the Series B bonds will constitute a single class of
debt securities under the indenture, as amended. If the exchange offer is
completed, holders of Series A bonds who do not exchange their Series A bonds
for Series B bonds will vote together with holders of the Series B bonds for all
relevant purposes under the indenture. In that regard, the indenture requires
that a number of actions by holders, including the acceleration following an
event of default, must be taken, and specific rights must be exercised, by
specified minimum percentages of the aggregate principal amount of the
outstanding securities issued under the indenture. In determining whether the
required holders have given any notice, consent or waiver or taken any other
action permitted under the indenture, any Series A bonds that remain outstanding
after the exchange offer will be aggregated with the Series B bonds, and the
holders of the Series A bonds and the Series B bonds will vote together as a
single series. All references in this prospectus to specified percentages in
aggregate principal amount of the notes means, at any time after the exchange
offer is completed, the percentages in aggregate principal amount of the Series
A bonds and the Series B bonds collectively then outstanding.
The term "bonds" as used in this prospectus refers collectively to the
Series A bonds and the Series B bonds. The bonds are senior to, and rank first
in priority with respect to all our current and future indebtedness.
PRINCIPAL AMOUNT, INTEREST RATE AND STATED MATURITY
The bonds will have an aggregate principal amount of $310,600,000 and will
bear interest at the rate of 8 1/2% per year. The bonds will mature on February
15, 2014.
Interest on the bonds will accrue at an annual rate of 8 1/2%. Any
defaulted principal, Make-Whole Premium or interest, and (to the extent lawful)
interest on such defaulted principal or interest, will bear interest at the rate
of 8 1/2% plus 1.0%. If an exchange offer is not consummated on or prior to the
279th day after the date of the original issue of the bonds, the annual interest
rate on the bonds will be increased by 1/2% until the date the exchange offer
is consummated or the date on which all of the bonds otherwise become
transferable by the holders of the bonds (other than affiliates of us). We will
pay interest on the bonds semi-annually on February 15 and August 15 or, if that
day is not a business day in New York City, then on the next succeeding business
day commencing February 15, 2001, to the registered owners thereof at the close
of business on the February 1 or August 1 preceding the relevant interest or
principal payment date. Interest will be computed on the basis of a 360-day year
consisting of twelve 30-day months.
We will repay principal on the bonds annually on February 15 or, if that
day is not a business day in New York City, the next succeeding business day,
commencing February 15, 2002.
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PAYMENT OF PRINCIPAL AND INTEREST
We will make all payments (including principal, Make-Whole Premium and
interest) on the bonds at the corporate trust office of the trustee or, at our
option, by check mailed to the address of the person entitled thereto, except
for the payment of the final installment of principal payable with respect to a
bond, which we will make upon presentation and surrender of that bond at the
corporate trust office of the trustee or such other place of payment as is
designated pursuant to the indenture. We will make these payments to the person
in whose name the bond (or one or more predecessor bonds) is registered at the
close of business on the regular record date (the fifteenth day next preceding
the relevant interest or principal payment date) for the payment.
Notwithstanding the foregoing, upon written request, we will make a payment on
the bonds (other than a final payment of principal) by wire transfer to holders
of $1 million or more aggregate principal amount of bonds. In the case of the
global bonds, these payments will be made to Depository Trust or to any nominee
thereof, which will be the holder of record of the global bonds. See "-- Form
and Denomination."
INSTALLMENT PAYMENTS OF PRINCIPAL
Installments of principal on the bonds are payable as follows:
PERCENTAGE OF PRINCIPAL
PAYMENT DATE AMOUNT PAYABLE
- ------------ -----------------------
February 15, 2002................................ 1.9
February 15, 2003................................ 2.5
February 15, 2004................................ 3.5
February 15, 2005................................ 4.9
February 15, 2006................................ 5.8
February 15, 2007................................ 6.7
February 15, 2008................................ 7.7
February 15, 2009................................ 8.8
February 15, 2010................................ 9.9
February 15, 2011................................ 11.3
February 15, 2012................................ 12.6
February 15, 2013................................ 14.3
February 15, 2014................................ 10.1
REDEMPTION AT OUR OPTION
We may at any time redeem all or any portion of the outstanding bonds, in
whole or in part, at a redemption price equal to the principal amount thereof to
be redeemed plus accrued and unpaid interest thereon to the redemption date,
plus the Make-Whole Premium, if any, on a redemption date that we will
establish.
We will mail a notice of any such redemption to each holder of a bond which
is to be redeemed (in whole or in part) at that holder's address of record not
less than 30 days nor more than 60 days before the applicable redemption date.
In addition, we will provide a notice of redemption of bonds to be redeemed to
the trustee in accordance with the terms of the indenture. On and after any such
redemption date, interest will cease to accrue on the bonds (or portion of the
principal amount thereof) called for redemption.
LIMITATION ON LIABILITY
There is no recourse for the payment of principal of or Make-Whole Premium,
if any, or interest on any bond, or for any claim based thereon or otherwise in
respect thereof, or of the indebtedness represented thereby, or upon any
obligation, covenant or agreement under the indenture or any bond, against any
of our affiliates or any incorporator, stockholder, member, officer, employee or
director of us or any such affiliate or any predecessor or successor thereof and
any such liability is expressly waived and
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released. Nothing, however, limits the liability of any of the foregoing for
fraud, gross negligence or willful misconduct.
FORM AND DENOMINATION
All bonds will be issued in registered form without coupons. The bonds may
be issued in minimum denominations of $100,000 and integral multiples of $1,000
in excess thereof. The bonds, and transfers thereof, will be registered as
provided in the indenture. Any person in whose name a bond is registered may to
the fullest extent permitted by applicable law be treated as the absolute owner
of that bond. The person in whose name a bond is registered is referred to in
this prospectus as the "holder" of a bond.
Except in the limited circumstances described under "-- Certificated Bonds"
below, beneficial interests in the global bonds will only be recorded by
book-entry and owners of beneficial interests in the global bonds will not be
entitled to receive physical delivery of certificates representing the bonds.
Except as set forth below, the Series B bonds will be represented by one
permanent global registered bond in global form without interest coupons, which
we refer to in this prospectus as the "global bonds." The global bonds will be
deposited with, or on behalf of, Depository Trust and registered in the name of
Cede & Co.
Global Bonds
Upon the issuance of the global bonds it is expected that, Depository Trust
or its nominee will credit, on its internal system, the respective principal
amounts of the individual beneficial interests represented by those global bonds
to the accounts of persons who have accounts with Depository Trust. These
accounts initially will be designated by or on behalf of the initial purchaser.
Ownership of beneficial interests in a global bond will be limited to persons
who have accounts with Depository Trust ("participants") or persons who hold
interests through participants. Ownership of beneficial interests in the global
bonds will be shown on, and the transfer of that ownership will be effected only
through, records maintained by Depository Trust or its nominee (with respect to
interests of participants) and the records of agent members (with respect to
interests of persons other than participants).
So long as Depository Trust or its nominee is the holder of a global bond,
Depository Trust or its nominee, as the case may be, will be considered the
holder of the bonds represented by that global bond for all purposes under the
indenture and the bonds. No beneficial owner of an interest in a global bond
will be able to transfer that interest except in accordance with Depository
Trust's applicable procedures (in addition to those under the indenture referred
to herein and, if applicable, those of Euroclear and Clearstream Luxembourg)
unless we issue certificates for the bonds in definitive registered form as
described under "-- Certificated Bonds" below.
Payments of the principal of, and interest and Make-Whole Premium, if any,
on the global bonds will be made to Depository Trust or its nominee, as the
holder thereof. Neither we, the initial purchaser nor the trustee will have any
responsibility or liability for any aspect of the records relating to or
payments made on account of beneficial ownership interests in the global bonds
or for maintaining, supervising or reviewing any records relating to those
beneficial ownership interests or the transfer thereof.
We expect that Depository Trust or its nominee, upon receipt of any payment
of principal of, or interest on, or Make-Whole Premium, if any, in respect of a
global bond held by it or its nominee, will immediately credit participants'
accounts with payments in amounts proportionate to their respective beneficial
interests in the principal amount of the global bond as shown on the records of
Depository Trust or its nominee. We also expect that payments by participants to
owners of beneficial interests in that global bond held through the participants
will be governed by standing instructions and customary practices. These
payments will be the responsibility of the participants.
Transfers between participants in Depository Trust will be effected in the
ordinary way in accordance with Depository Trust rules and will be settled in
same-day funds. The laws of some jurisdictions may require that some persons
take physical delivery of bonds in definitive form. Consequently, the ability to
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transfer beneficial interests in a global bond to these persons may be limited.
Because Depository Trust can only act on behalf of participants, who in turn act
on behalf of indirect participants and specified banks, the ability of a person
having a beneficial interest in a global bond to pledge that interest to persons
or entities that do not participate in the Depository Trust system, or otherwise
take actions in respect of that interest, may be affected by the lack of a
physical certificate representing that interest. Transfers between participants
in Euroclear and 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
bonds described above and under "Transfer Restrictions," cross-market transfers
between Depository Trust, on the one hand, and directly or indirectly through
Euroclear or Clearstream Luxembourg participants, on the other, will be effected
in Depository Trust in accordance with Depository Trust rules on behalf of
Euroclear or Clearstream Luxembourg, as the case may be, by its respective
depositories; however, these cross-market transactions will require delivery of
instructions to Euroclear or Clearstream Luxembourg, as the case may be, by the
counterparty in such system in accordance with its rules and procedures and
within its established deadlines. Euroclear or Clearstream Luxembourg, as the
case may be, will, if the transaction meets its settlement requirements, deliver
instructions to its respective depositories to take action to effect final
settlement on its behalf by delivering or receiving interests in the global bond
in Depository Trust, and making or receiving payment in accordance with normal
procedures for same-day funds settlement applicable to Depository Trust.
Euroclear and Clearstream Luxembourg participants may not deliver instructions
directly to the depositories for Depository Trust.
Because of time zone differences, the bond account of a Euroclear or
Clearstream Luxembourg participant purchasing an interest in a global bond from
a Depository Trust participant will be credited during the bonds settlement
processing day (which must be a business day for Euroclear or Clearstream
Luxembourg, as the case may be) immediately following the Depository Trust
settlement date, and the credit of any transactions in interests in a global
bond settled during a processing day will be reported to the relevant Depository
Trust participant on that day. Cash received in Euroclear or Clearstream
Luxembourg as a result of sales of interests in a global bond by or through a
Euroclear or Clearstream Luxembourg participant to a Depository Trust
participant will be received on the Depository Trust settlement date, but will
be available in the relevant Euroclear or Clearstream Luxembourg cash account
only as of the business day following settlement in Depository Trust.
We expect that Depository Trust will take any action permitted to be taken
by a holder of bonds (including the presentation of bonds for exchange as
described below) only at the direction of one or more participants to whose
Depository Trust account interests in the global bond are credited, and only in
respect of that portion of the aggregate principal amount of the bonds as to
which that participant or those participants has or have given such direction.
Depository Trust is a limited purpose trust company organized under the
laws of the State of New York; a member of the Federal Reserve System; a
"clearing corporation" within the meaning of the New York Uniform Commercial
Code; and a "clearing agency" registered pursuant to the provisions of Section
17A of the Securities Exchange Act. Depository Trust was created to hold bonds
for its participants and facilitate the clearance and settlement of bond
transactions between participants through electronic book-entry changes in
accounts of its participants, thereby eliminating the need for physical movement
of certificates. Participants include bonds brokers and dealers, banks, trust
companies and clearing corporations and may include other organizations.
Indirect access to the Depository Trust system is available to others such as
banks, brokers, dealers and trust companies that clear through or maintain a
custodial relationship with a Depository Trust participant, either directly or
indirectly.
Although Depository Trust, Euroclear and Clearstream Luxembourg have agreed
to the foregoing procedures in order to facilitate transfers of interest in the
global bonds among participants of Depository Trust, Euroclear and Clearstream
Luxembourg, they are under no obligation to continue to perform such procedures,
and such procedures may be discontinued at any time. Neither we, the initial
purchaser nor the trustee will have any responsibility for the performance by
Depository Trust, Euroclear or Clearstream
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Luxembourg or their respective participants or indirect participants of their
respective obligations under the rules and procedures governing their
operations.
Certificated Bonds
The bonds will be issued in certificated fully registered form (which we
refer to as the individual bonds) to holders or their nominees, rather than as
global bonds if:
- we notify the trustee in writing that Depository Trust or any successor
depositary, as the case may be, is unwilling or unable to continue as a
depositary for a global bond or ceases to be a depositary and we are
unable to locate a qualified successor depositary within 90 days of this
notice;
- we elect to terminate the book-entry system through Depository Trust with
respect to the bonds; or
- after the occurrence of an event of default, the beneficial owners
holding interests representing an aggregate principal amount of bonds of
not less than a majority of the bonds represented by the global bonds
advise the trustee through Depository Trust in writing that the
continuation of a book-entry system through Depository Trust is no longer
in their best interest.
The holder of an individual bond may transfer the bond by surrendering it
at the corporate trust office or agency maintained by us for such purpose in the
Borough of Manhattan, The City of New York, which initially will be the office
of the trustee.
THE ACCOUNTS
Establishment of Accounts
Pursuant to the indenture, the trustee established and maintains the
following accounts and subaccounts in its own name for the benefit of the
holders (collectively, the "accounts"):
- the collections account;
- the liquidity account; and
- the damages and indemnity account.
Collections Account
We have instructed each person from whom we receive or are entitled to
receive collections to pay those collections (identifying them as such) directly
to the trustee for deposit in the collections account. On the closing date of
the offering of the Series A bonds, the collections account was funded by an
amount equal to $2,396,509 from the proceeds of the offering of the Series A
bonds. The trustee must deposit into the collections account all transfer
payments from the liquidity account as described in the third paragraph of the
section entitled "-- Liquidity Account" and amounts on deposit in the
collections account will be withdrawn as described in "-- Withdrawals from the
Collections Account."
Liquidity Account
The liquidity account was funded on the closing date of the offering of the
Series A bonds by the transfer to the trustee and the deposit into the liquidity
account of an amount equal to the maximum amount of interest that will be due on
February 15, 2001 from the net proceeds of the offering of the Series A bonds.
The Liquidity Account will also be funded by the transfer by the trustee on each
interest payment date of funds from the collections accounts to the liquidity
account as described under priority fifth of "-- Withdrawals from the
Collections Account," such that the amount in the liquidity account is
sufficient to make the next interest payment due on the bonds.
At any time El Paso may withdraw amounts on deposit in the liquidity
account if El Paso delivers to the trustee for allocation to the liquidity
account to replace the amount withdrawn, either (1) a guaranty issued by El Paso
in the amount withdrawn, in favor of the trustee for the benefit of the holders
or
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(2) one or more letters of credit in an aggregate face amount equal to all or a
portion of the then current liquidity reserve required balance. In order for El
Paso to be able to use the guaranty described in (1) El Paso must have and
maintain at least the following ratings: P-1 (or its equivalent) from Moody's
and A-1 (or its equivalent) from Standard & Poor's. Each such letter of credit
described in (2) must (A) be from a financial institution rated at least Aa3 (or
its equivalent) by Moody's and AA -- (or its equivalent) by Standard & Poor's;
(B) name the trustee as its sole beneficiary; and (C) provide that the trustee
may unconditionally draw, upon presentation of the documentation required by
such letter of credit, under any circumstances that would otherwise permit
withdrawals from the liquidity account or at any time within 30 days before the
expiration of that letter of credit (unless the validity of the letter of credit
is extended or the letter of credit is replaced with another letter of credit
that meets the requirements of the indenture).
If on any interest payment date or principal payment date, as applicable,
the aggregate amount of funds on deposit in and available to be withdrawn from
the collections account is insufficient for the payment of principal or interest
then due and payable on the bonds (any such deficiency, a "Liquidity
Deficiency"), the trustee will transfer from the liquidity account to the
collections account an amount equal to the Liquidity Deficiency. If on any
interest payment date the aggregate amount of funds on deposit in and available
to be withdrawn from the liquidity account exceeds the then current liquidity
reserve required balance, the excess funds will be transferred on the next
principal payment date (but no earlier than February 15, 2003) to the
collections account. If the cash in the liquidity account has been replaced by a
letter of credit, the trustee will not draw on the letter of credit for the
amount of such excess, but will take such action on the next principal payment
date (but no earlier than February 15, 2003) as El Paso will reasonably direct
in writing to the trustee to reduce the amount available to be drawn under the
letter of credit by the amount of the excess.
Damages and Indemnity Account
We will instruct El Paso Merchant and El Paso to pay to the trustee for
deposit into the damages and indemnity account all amounts to be paid by El Paso
Merchant under the power services agreement and all amounts to be paid by El
Paso under the El Paso performance guaranty to cover:
- damages payable by us to Public Service Electric pursuant to Article XIV
of the amended power purchase agreement;
- indemnity payments payable by us to Public Service Electric pursuant to
Article XII of the amended power purchase agreement; and
- distribution charges payable by us to Public Service Electric pursuant to
Article II(E) of the amended power purchase agreement.
Funds will be withdrawn from the damages and indemnity account from time to
time as needed to pay:
- damages payable by us to Public Service Electric pursuant to Article XIV
of the amended power purchase agreement;
- indemnity payments payable by us to Public Service Electric pursuant to
Article XII of the amended power purchase agreement; and
- distribution charges payable by us to Public Service Electric pursuant to
Article II(E) of the amended power purchase agreement.
WITHDRAWALS FROM THE COLLECTIONS ACCOUNT
Unless a holder has given notice of an event of default or notice that a
bankruptcy event of default has occurred and is continuing, the trustee will
apply amounts in the collections account on the following
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dates and in the following order of priority (if a date is specified and that
date is not a business day in New York, the payment will be made on the next
business day in New York):
(1) first, on the fifteenth day of each month, to pay to the trustee
the amount of trustee fees due and payable at such time in connection with
the bonds;
(2) second, on the fifteenth day of each month, to pay to El Paso
Merchant, for energy and capacity provided under the power services
agreement for the month prior to the most recently ended month (as
specified in our officer's certificate);
(3) third, on each interest payment date, to pay, pro rata, to the
holders of the bonds an amount equal to the interest due and payable at
that time on the bonds;
(4) fourth, on each principal payment date, to pay, pro rata, to the
holders of the bonds an amount equal to the principal and Make-Whole
Premium (if any) due and payable at that time on the bonds;
(5) fifth, on each interest payment date, to transfer to the liquidity
account an amount, if any, necessary to cause the amount on deposit in the
liquidity account to be equal to the liquidity reserve required balance;
(6) sixth, on each interest payment date, to pay to El Paso Merchant
an amount equal to the accrued and unpaid fees and expenses owed El Paso
Merchant under the administrative services agreement; and
(7) seventh, on each principal payment date or on February 15, 2001,
provided that (as specified in our officer's certificate) (A) no event of
default or default has occurred and is continuing on such date and (B) the
Debt Service Reserve Coverage Ratio calculated as of that date for the most
recently ended six-month period equals or exceeds 1.03 to 1.00, to us for
distribution to our members.
INVESTMENT OF FUNDS
The trustee will invest the moneys on deposit in the accounts in Permitted
Investments as directed by us. Profits from Permitted Investments will be
deposited into the collections account. Losses on Permitted Investments will be
charged to the applicable account. The trustee has the right to sell or
otherwise liquidate any Permitted Investments to the extent necessary to make
any payment or transfer under the indenture and will have no liability for any
losses incurred in connection with the sale or liquidation.
COVENANTS IN THE INDENTURE
The indenture contains the following covenants, among others:
Material Agreements
We will enforce our rights under each of our material agreements unless the
failure to enforce those rights could not reasonably be expected to result in a
material adverse effect.
Performance of Obligations
We may contract with other persons to assist us in performing our
obligations, and, if we do, the performance by that person or those persons will
be treated the same as if we had performed the obligation ourselves. As of the
closing date of the offering of the Series A bonds, we contracted with El Paso
Merchant to perform our obligations under the indenture and the other financing
documents, so any action taken by El Paso Merchant in performing our duties will
be treated as an action taken by us.
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Liens
We will not create or permit to exist any lien on any of the collateral,
other than the liens created by the indenture, unless the existence of the lien
could not reasonably be expected to result in a material adverse effect.
Indebtedness
We will not create or permit to remain outstanding, any indebtedness,
except for indebtedness represented by the bonds issued on the closing date.
Guaranties
We will not at any time be or become obligated, contingently or otherwise,
with respect to any guaranty.
Transactions with Affiliates
We will not effect any transaction with any of our affiliates on a basis
more favorable to this affiliate than would be at the time be obtainable for a
comparable transaction on an arm's-length dealing with an unrelated third party,
except for (1) our material agreements entered into on or before the closing
date or (2) in connection with any restructuring of the assets of Mesquite.
Investments, Loans and Advances
Except for Permitted Investments, we will not acquire any capital stock,
debt securities or other securities of any other person and we will not make
investments in any other person.
Material Agreements; Additional Contracts
We will not assign any of our rights or obligations under any of our
material agreements nor terminate or suffer any termination of, or agree to the
assignment of the rights or obligations of any party to, any of our material
agreements.
We will not amend or grant any waiver of timely performance under any of
our material agreements or financing documents, unless the amendment or waiver
could not reasonably be expected to result in a material adverse effect.
We will not become a party to any contract, lease, agreement or instrument
other than the agreements expressly identified in the definition of our material
agreements and financing documents to the extent the action could reasonably be
expected to result in a material adverse effect.
Fundamental Change
We will undertake not to do any of the following:
- sell, lease, transfer or otherwise dispose of any of our right, title or
interest in or to the collateral, unless doing so could not reasonably be
expected to result in a material adverse effect;
- conduct any business or own any assets other than the business and assets
conducted and owned by us as of the closing date of the offering of the
Series A bonds;
- directly or indirectly merge or consolidate with any other person,
liquidate, wind up, terminate, reorganize or dissolve ourselves, or
otherwise wind up;
- change our legal form; or
- establish any subsidiary.
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Maintenance of Market-Based Rate Authority
We will take all actions, if required, necessary to maintain our Federal
Energy Regulatory Commission market-based rate authority and will maintain in
effect all governmental approvals required to conduct our business under our
material agreements.
Restricted Payments
Except in accordance with the conditions set forth in clause seventh of
"-- Withdrawals from the Collections Account," we will not, directly or
indirectly,
- make any distribution (by reduction of capital or otherwise), whether in
cash, property, securities or a combination thereof, to our members or
any owner of a beneficial interest in us or otherwise with respect to any
ownership or equity interest or security in or of us;
- redeem, purchase, retire or otherwise acquire for value any such
ownership or equity interest or security; or
- set aside or otherwise segregate any amounts for any such purpose.
We will not, directly or indirectly, make payments to or distributions from
the collections account except in accordance with the indenture and the
financing documents. See "-- Withdrawals from the Collections Account."
ADDITIONAL COVENANTS
In addition to the covenants described above, the indenture also contains
covenants regarding:
- payment of principal, Make-Whole Premium and interest;
- maintenance of office or agency;
- maintenance of existence and properties;
- payment of taxes and other claims;
- delivery to the trustee of notice, compliance certificates and other
specified information, including the existence of a default or event of
default;
- taking of all actions to preserve liens in favor of the trustee under the
financing documents;
- complying with all applicable laws and all of our obligations under the
indenture, the other financing documents, our material agreements and
each of our other agreements, unless, in each case, the failure to comply
could not reasonably be expected to result in a material adverse effect;
- maintenance of books and records;
- maintenance of and compliance with Governmental Approvals;
- schedule and deliver the annual energy deliveries;
- furnishing to the trustee within 120 days after the end of each fiscal
year an officer's certificate stating that no default has occurred and is
continuing; and
- further assurances.
EVENTS OF DEFAULT
An event of default will occur under the indenture (an "event of default")
if:
(1) we default in the payment of any principal of or Make-Whole
Premium, if any, on any of the bonds when the same becomes due and payable,
whether by scheduled maturity or acceleration or otherwise, and such
default continues for a period of at least five days;
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(2) we default in the payment of interest on, or any other amount
required to be paid with respect to, any of the bonds (other than principal
or Make-Whole Premium) in each case when the same becomes due and payable,
and the default continues for a period of at least 15 days;
(3) El Paso or Public Service Electric or we fail to observe or
perform any covenant or provision of any of our material agreements or
financing document to which El Paso or Public Service Electric or we, as
the case may be, are a party, and the failure (a) could reasonably be
expected to result in a material adverse effect and (b) continues for a
period of at least 30 days after the date notice thereof has been given to
us by the trustee or the holders of not less than 51% in aggregate
principal amount of the outstanding bonds;
(4) any of our material agreements or financing documents ceases at
any time to be valid and binding and in full force and effect and the
invalidity and unenforceability could reasonably be expected to result in a
material adverse effect;
(5) (A) any grant of a lien contained in the indenture or in any
financing document ceases or otherwise fails to be effective to grant a
lien to the trustee on any material portion of the collateral described
therein, or ceases to be perfected or to be a first priority security
interest, or (B) any creditor of ours (other than the trustee or any bond
holder) asserts any right or interest with respect to the collateral and
the assertion could reasonably be expected to result in a material adverse
effect or (C) our right to receive payments with respect to the collateral
is terminated or impaired and this occurrence could reasonably be expected
to result in a material adverse effect;
(6) events occur involving our bankruptcy, insolvency or receivership,
among those the commencement of a proceeding seeking our liquidation or
reorganization or the appointment of a trustee or receiver relating to our
bankruptcy or insolvency and such proceeding continues unstayed for 60
consecutive days, as well as the filing by us of a voluntary bankruptcy
proceeding;
(7) it becomes unlawful for us to perform any of our obligations under
the indenture or any bond, or any of our obligations thereunder ceases to
be valid, binding and enforceable, unless such event or occurrence could
not reasonably be expected to result in a material adverse effect;
(8) for any reason the amended power purchase agreement or the El Paso
performance guaranty are terminated or abrogated at any time (prior to
their scheduled expiration);
(9) a final and non-appealable judgment or judgments for the payment
of money in excess of $15 million in the aggregate, which is not adequately
covered by insurance or a payment or performance bond, is entered against
us and the judgment or judgments have not been vacated, discharged, stayed
or bonded pending appeal within 60 days from the entry thereof; or
(10) we fail to observe or perform any covenant or provision of
Section 3(b) of the registration rights agreement (pursuant to which we are
obligated to use commercially reasonable efforts to continue the
effectiveness of a registration statement) and such failure continues for a
period of at least 30 days after the date notice has been given to us by
the trustee or the holders of not less than 51% in aggregate principal
amount of the outstanding bonds.
REMEDIES
If an event of default (other than events of default specified in
subparagraph (6) of the section "-- Events of Default" above (a "bankruptcy
event of default")) occurs and is continuing, then the trustee upon the
direction of no less than 25% (for an event of default with respect to failure
to make payments on the bonds) or the holders of not less than 51% in aggregate
principal amount of the outstanding bonds (for any other event of default) must
declare the principal amount of all the bonds to be due and payable immediately,
and upon any such declaration the principal amount, any accrued and unpaid
interest, any Make-Whole Premium and all other amounts payable under the bonds
will become immediately due and payable.
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If a bankruptcy event of default occurs, the principal amount of, any
accrued interest on, any Make-Whole Premium and all other amounts payable under
the outstanding bonds will become immediately due and payable.
In addition, if one or more of the Events of Default (other than a
bankruptcy event of default) occurs and is continuing, the trustee may
accelerate the maturity of the bonds notwithstanding the absence of direction
from the holders, if in the judgment of the trustee this action is necessary to
protect the interests of the holders.
At any time after the principal of the bonds becomes due and payable upon a
declared acceleration, and before any judgment or decree for the payment of the
money so due, or any portion thereof, is entered, the holders of not less than
51% in aggregate principal amount of the outstanding bonds, by written notice to
us and the trustee, may rescind and annul the declaration and its consequences
if all Events of Default giving rise to the acceleration have been cured or
waived.
At any time after a declaration of acceleration under the indenture, but
before a judgment or decree for payment of the principal amount of the bonds
then due has been obtained by the trustee, we may, by written notice to a
responsible officer of the trustee, rescind and annul such declaration and its
consequences if we have paid or deposited with the trustee a sum sufficient to
pay:
- all overdue interest on the bonds;
- all unpaid principal of and premium, if any, on any outstanding bonds
that have become due otherwise then by the declaration of acceleration
and interest thereon at the rate borne by the bonds;
- to the extent that payment of interest is lawful, interest upon overdue
interest and overdue principal at the rate borne by the bonds;
- all sums paid or advanced by the trustee under the indenture and the
reasonable compensation, expenses, disbursements and advances of the
trustee, its agents and counsel; and
- all defaults and events of default, other than the non-payment of amounts
of principal of, premium, if any, or interest on the bonds that have
become due solely by such declaration of acceleration and have been cured
or waived as provided in the indenture.
Subject to the provisions of the indenture relating to the duties of the
trustee, in case an event of default occurs and is continuing, the trustee is
under no obligation to exercise any of the rights or powers vested in it under
the indenture at the request or direction of any of the holders unless it is
offered security or indemnity reasonably satisfactory to it against costs,
expenses and liabilities.
If any event of default occurs and is continuing, the trustee may and, at
the written instruction of the holders of not less than 51% in aggregate
principal amount of the outstanding bonds, shall, exercise any or all of the
following rights and remedies:
- collect, receive and appropriate any or all of the collateral and
exercise any of our rights, remedies, powers or privileges under any of
our material agreements;
- set off against all amounts due and payable under the indenture funds on
deposit in the accounts;
- proceed by suit at law or in equity to seek specific performance of any
obligation of ours;
- take possession of the collateral, in which case we will deliver the
collateral to the trustee or its designee at the time or times and the
place or places as the trustee may reasonably specify;
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- sell, lease, assign, give an option or options to purchase or otherwise
dispose of and deliver all or any part of the collateral (or contract to
do so) at one or more public or private sales, at any exchange, broker's
board or at any of the trustee's offices or elsewhere at the prices as it
may deem best, for cash or on credit or for future delivery without
assumption of any credit risk; provided that, if the proceeds of such
sale or sales are not sufficient to satisfy all of the outstanding
principal, accrued and unpaid interest, any Make-Whole Premium and other
amounts due under the bonds, all of the Holders shall have consented to
such sale or sales;
- proceed by suit at law or in equity to foreclose upon, or appoint a
receiver with respect to, the collateral or exercise any other right or
remedy (including specific performance of our obligations under the
financing documents) available under applicable law.
APPLICATION OF MONEY COLLECTED
Any money collected by the trustee pursuant to its exercise of remedies
under the indenture will be applied in the following order of priority:
- first, to the payment of all amounts due to the trustee and each
predecessor trustee, if any, under the indenture;
- second, to the payment of the amounts when due and unpaid for principal
of (and Make-Whole Premium, if any) and any interest on the bonds in
respect of which or for the benefit of which the money has been
collected, ratably, without preference or priority of any kind, according
to the amounts due and payable on the bonds for principal (and Make-Whole
Premium, if any) and any interest, respectively;
- third, to the payment of all amounts due and payable to El Paso Merchant
under the Administrative Services and the power services agreement, as
set forth in our officer's certificate or as determined by a court of
competent jurisdiction; and
- fourth, to us.
AMENDMENTS AND SUPPLEMENTS
Without the consent of the holders of the bonds, we and the trustee may
enter into one or more supplemental indentures for any of the following
purposes:
- to evidence the succession of another person to us and the assumption by
any such successor of our covenants contained in the indenture and in the
bonds;
- to add to our covenants for the benefit of the holders of the bonds or to
surrender any right or power conferred upon us in the indenture;
- to add any additional Events of Default;
- to secure the bonds;
- to evidence and provide for the acceptance of appointment by a successor
trustee with respect to the bonds and to add to or change any of the
provisions of the indenture as shall be necessary to provide for or
facilitate the administration of the trusts thereunder by more than one
trustee;
- to cure any ambiguity, to correct or supplement any provision of the
indenture which may be inconsistent with any other provision therein, or
to make any other provisions with respect to matters or questions arising
under the indenture; provided that action shall not adversely affect the
interests of the holders of bonds in any material respect; or
- to supplement any of the provisions of the indenture to the extent as
shall be necessary to permit or facilitate the defeasance and discharge
of the bonds; provided that any such action does not adversely affect the
interests of the holders of the bonds in any material respect.
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With the consent of the holders of a majority of all outstanding bonds, we
and the trustee may enter into an indenture or indentures supplemental to the
indenture for the purpose of adding any provisions to or changing in any manner
or eliminating any of the provisions of the indenture or of modifying in any
manner the rights of the holders of bonds under the indenture; provided,
however, that no such supplemental indenture will, without the consent of the
holder of each outstanding bond affected thereby:
- change the stated maturity of the principal of, or any installment of
interest on, any bond;
- reduce the principal amount or interest on or any Make-Whole Premium
payable upon the redemption of any bond including discharge of repayment
of principal of or interest on any bond;
- reduce the percentage in principal amount of outstanding bonds, the
consent of the holders of which is required for the adoption of a
resolution or the quorum required at any meeting of holders at which a
resolution is adopted or the percentage in principal amount of
outstanding bonds the holders of which are entitled to request the
calling of a holder's meeting;
- change the percentage rules established for adopting resolutions at
meetings of holders or regarding the quorum necessary to constitute a
meeting;
- modify any of the provisions of the indenture regarding the approval of
supplemental indentures or waiver of past default, except to increase the
percentage of required holders for those approvals;
- change the place or coin or currency for payment of principal of,
Make-Whole Premium or interest on, any bond;
- impair the right to institute suit for the enforcement of any payment on
or after the stated maturity thereof or any redemption date therefor;
- permit the creation of any lien with respect to all or any substantial
portion of the collateral, or terminate the lien of the security
documents on all or any substantial portion of the collateral or deprive
any holder of the security afforded by the lien of the security
documents, except to the extent expressly permitted by the indenture or
any of the financing documents;
- modify the ranking or priority of the bonds; or
- waive a default in the payment of principal of, Make-Whole Premium, if
any, or interest on the bonds.
SATISFACTION AND DISCHARGE OF THE INDENTURE
The indenture will cease to be of further effect (except as to any
surviving rights of registration of transfer or exchange of bonds expressly
provided for and except as otherwise specifically provided in the indenture)
when:
(1) either
(A) all bonds previously authenticated and delivered (other than (i)
bonds which have been destroyed, lost or stolen and which have been
replaced or paid and (ii) bonds for whose payment money has previously been
deposited in trust with the trustee) have been delivered to the trustee for
cancellation; or
(B) all bonds not previously delivered to the trustee for cancellation
(i) have become due and payable,
(ii) will become due and payable at their stated maturity within
one year, or
(iii) if redeemable at our option, are to be called for redemption
within one year under arrangements satisfactory to the trustee for the
giving of notice of redemption by the trustee in our name and at our
expense; and we, in the case of (B)(i), (ii) or (iii) above, have
irrevocably deposited or caused to be deposited with the trustee as
trust funds in trust for the purpose an
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amount sufficient to pay and discharge the entire indebtedness on those
bonds not previously delivered to the trustee for cancellation, for
principal, Make-Whole Premium, if any, and interest to the date of the
deposit (in the case of bonds which have become due and payable) or to
the stated maturity or redemption date, as the case may be;
(2) we have paid or caused to be paid all other sums payable under the
indenture by us; and
(3) we have delivered to the trustee an officer's certificate and an
opinion of counsel, each stating that all conditions precedent relating to the
satisfaction and discharge of the indenture as to the bonds have been complied
with.
DEFEASANCE OR COVENANT DEFEASANCE
We may, at our option, elect to be discharged from our obligations with
respect to the outstanding bonds ("defeasance"). This defeasance means that we
will be deemed to have paid and discharged the entire indebtedness represented
by such outstanding bonds and to have satisfied all our other obligations under
those bonds and the indenture insofar as those bonds are concerned, except for
the following which shall survive until otherwise terminated or discharged:
- the rights of holders of the outstanding bonds to receive, solely from
the trust funds, payments in respect of the principal of and interest and
Make-Whole Premium on those bonds when those payments are due;
- ministerial obligations with respect to registration, payment and
transfer of the bonds and similar matters;
- the rights, powers, trusts, duties and immunities of the trustee under
the indenture; and
- the defeasance provisions of the indenture.
In addition, we may also elect to have covenant defeasance apply. In the
event covenant defeasance occurs, (1) we will be released from our covenants
contained in the indenture, except for the covenants concerning the payment of
principal, interest and Make-Whole Premium, maintenance of office or agency and
maintenance of existence and properties; and (2) thereafter, failure to comply
with all covenants except those listed in clause (i) above will not be deemed to
be an event of default.
In order to exercise either defeasance or covenant defeasance with respect
to any outstanding bonds a number of conditions must be satisfied, including the
following:
- we must irrevocably deposit or cause to be deposited with the trustee an
amount sufficient to pay and discharge the outstanding principal of and
unpaid installments of interest (and Make-Whole Premium, if any) on the
outstanding bonds on the date when those payments become due;
- we must deliver opinions of counsel and an officer's certificate as to
specified matters;
- we must certify that the bonds, if then listed on any securities
exchange, will not be delisted as a result of such deposit;
- no default or event of default with respect to the outstanding bonds will
have occurred and be continuing on the date of the deposit or, insofar as
paragraph (6) under "-- Events of Default" is concerned, at any time
during the period ending on the 121st day after the date of the deposit;
- the defeasance or covenant defeasance will not result in a breach or
violation of, or constitute a default under, the indenture or any other
material agreement or instrument to which we are a party or by which we
are bound; and
- the defeasance or covenant defeasance will not result in the trust
arising from the deposit constituting an investment company as defined in
the Investment Company Act of 1940, as amended, or the trust will be
qualified under the act or exempt from regulation thereunder.
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THE TRUSTEE
Bankers Trust Company is the trustee under the indenture. The trustee's
current address is 4 Albany Street, New York, New York 10006, Attention:
Corporate Trust Office.
COLLATERAL SECURITY
We granted to the trustee at the closing date, on behalf of and for the
benefit of the holders, all of our right, title and interest in and to:
- the amended power purchase agreement;
- the power services agreement;
- the administrative services agreement;
- our other material agreements;
- the collections and all amounts payable to us arising out of,
attributable to, in respect of or otherwise in connection with the
collections;
- all other amounts payable to us pursuant to our material agreements;
- the collections account, the liquidity account and the damages and
indemnity account and all funds and all investments and proceeds on
deposit therein from time to time;
- all our governmental approvals and general intangibles;
- all damages and other amounts payable to us in respect of the foregoing;
- all of our rights, claims, powers, privileges and remedies (whether
mandatory, discretionary or judgmental), whether arising by contract, at
law, in equity or otherwise with respect to the foregoing; and
- all present and future claims and demands in respect of any or all of the
foregoing, insurance proceeds, condemnation awards and all payments and
all proceeds of every kind and nature whatsoever in respect of any or all
of the foregoing (collectively, the "collateral").
REPORTS TO HOLDERS
While we are not required to nor do we intend to send annual reports to the
holders of the bonds, we will be filing the reports required by the Securities
Exchange Act and copies of our filings with the SEC will be provided to the
trustee.
MEETINGS OF HOLDERS
The trustee will call, upon the request of the holders of at least 10% in
aggregate principal amount of the outstanding bonds or our request, or, in the
event the trustee fails to call such a meeting, we or the holders of at least
10% in aggregate principal amount of the outstanding bonds may call, or the
trustee at its discretion, may call, a meeting of the holders at any time and
from time to time, to:
- give any notice to us or to the trustee, or to give any directions to the
trustee, or to waive or to consent to the waiving of any default under
the indenture and its consequences, or to take any other action
authorized to be taken by holders in connection with the occurrence of an
event of default;
- remove the trustee pursuant to the indenture;
- consent to the execution of a supplemental indenture; or
- take any other action authorized to be taken by or on behalf of the
holders of any specified aggregate principal amount of the bonds under
any other provision of the indenture or under applicable law.
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Meetings will be held at such time and at such place in the Borough of
Manhattan, the City of New York as the trustee or we or the holders of not less
than 10% in aggregate principal amount of the outstanding bonds at the time
determine. Notice of any meeting of holders setting forth the time and the place
of that meeting and in general terms the action proposed to be taken at that
meeting will be given by the trustee not less than 20 days nor more than 120
days prior to the date fixed for the meeting.
Any holder may attend the meeting in person or by proxy.
At any meeting, the presence of persons holding or representing bonds with
respect to which the meeting is being held in an aggregate principal amount
sufficient to take action upon the business for the transaction of which the
meeting was called will be necessary to constitute a quorum; but, if less than a
quorum is present, the persons holding or representing a majority of the bonds
represented at the meeting may adjourn the meeting with the same effect, for all
intents and purposes, as though a quorum had been present. At any meeting, each
holder of a bond or a proxy will be entitled to one vote for each $1,000
principal amount of bonds held or represented by it.
GOVERNING LAW AND ENFORCEABILITY
The indenture and the bonds are governed by, and construed in accordance
with, the laws of the State of New York.
We have consented to the non-exclusive jurisdiction of any court of the
State of New York or any United States federal court sitting in The Borough of
Manhattan, New York City, New York, United States, and any appellate court from
any thereof, and have waived any immunity from the jurisdiction of these courts
over any suit, action or proceeding that may be brought in connection with the
indenture or the bonds.
We irrevocably appointed CT Corporation System as our authorized agent upon
which all writs, process and summonses may be served in any suit, action or
proceeding brought in connection with the indenture or the bonds against us in
any court of the State of New York or any United States federal court sitting in
the Borough of Manhattan, New York City and will agree that this appointment
will be irrevocable so long as any of the bonds remain outstanding or until the
irrevocable appointment by us of a successor in New York City as our authorized
agent for such purpose and the acceptance of this appointment by the successor.
DEFINED TERMS
"Debt Service Reserve Coverage Ratio" means, for any period, the ratio
which is equal to (a) Net Collections for that period divided by (b) Mandatory
Debt Service for that period. For the purposes of this definition, "Net
Collections" means for any period, the excess, if any, of (a) the sum of the
collections and the transfer payments from the liquidity account to the
collections account over (b) any amount payable during that period pursuant to
clauses (1)-(2) of the Section "-- Withdrawals from the Collections Account" and
"Mandatory Debt Service" means, for any period, all scheduled interest and
principal payments and fees payable during that period in respect of the bonds.
"Independent Investment Banker" means Credit Suisse First Boston
Corporation or its successor.
"Make-Whole Premium" means an amount equal to the Discounted Present Value
calculated for any bond subject to redemption less the unpaid principal amount
of that bond; provided that the Make-Whole Premium shall not be less than zero.
For purposes of this definition, the "Discounted Present Value" of any bond
subject to redemption shall be equal to the discounted present value of all
principal and interest payments scheduled to become due in respect of that bond
after the date of this redemption, calculated by the Independent Investment
Banker using a discount rate equal to the sum of (1) the yield to maturity on
the United States treasury security having an average life equal to the
remaining average life of that bond and trading in the secondary market at the
price closest to par and (2) 50 basis points; provided, however, that, if there
is no United States treasury security having an average life equal to the
remaining average life of that bond, this discount rate shall be calculated
using a yield to maturity interpolated or
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extrapolated on a straight-line basis (rounding to the nearest month, if
necessary) from the yields to maturity for two United States treasury securities
having average lives most closely corresponding to the remaining average life of
that bond and trading in the secondary market at the price closest to par.
"Permitted Investments" means the following investments maturing, in each
case, not less than one business day before the interest payment date next
following the date such investment is made; provided, however, that in the case
of any investment pursuant to clause (b) of this definition which is made with
the trustee, such investment may mature on such interest payment date:
(a) any direct obligations of, or obligations fully guaranteed by, the
United States of America, or any agency or instrumentality of the United
States of America, the obligations of which are fully backed by the full
faith and credit of the United States of America;
(b) demand and time deposits in, certificates of deposit of, bankers'
acceptances issued by, or federal funds sold by any depository institution
or trust company incorporated under the laws of the United States of
America or any State thereof and subject to supervision and examination by
federal and/or state authorities, or incorporated under the laws of any
other jurisdiction, so long as at the time of such investment or
contractual commitment providing for such investment the unsecured
commercial paper or other unsecured short-term debt obligations of such
depository institution or trust company have at least the Required Credit
Rating from Moody's and Standard & Poor's;
(c) repurchase obligations with respect to any security described in
clauses (a) or (b) above, in each case entered into with either (i) a
depository institution or trust company (acting as principal) which in
respect of its short-term unsecured debt has at least the Required Credit
Rating from Moody's and Standard & Poor's; or (ii) a money market fund
maintained by a broker which in respect of its short-term unsecured debt
has at least the Required Credit Rating from Moody's and Standard & Poor's;
(d) unsecured debt securities bearing interest or sold at a discount
issued by any corporation incorporated under the laws of the United States
of America, or any State thereof, which have at the time of such investment
at least the Required Credit Rating from Moody's and Standard & Poor's;
(e) unsecured commercial paper which has at the time of such
investment at least the Required Credit Rating from Moody's and Standard &
Poor's; and
(f) investments in money market funds or money market mutual funds
which have at the time of such investment at least the Required Credit
Rating from Moody's and Standard & Poor's (including such funds for which
the trustee or any of its affiliates is investment manager or advisor and
for which the trustee or any of its affiliates may receive a fee).
"Required Credit Rating" means P-l (or its equivalent) from Moody's and A-l
(or its equivalent) from Standard & Poor's.
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DESCRIPTION OF OUR PRINCIPAL FINANCING DOCUMENTS
The following summaries of material provisions of the financing documents
(other than the indenture and the bonds which are described in "Description of
the Bonds") do not purport to be complete. Copies of such financing documents
are available for inspection at the corporate trust office of the trustee. We
urge you to read such financing documents because they, and not this
description, define your rights as holder of the bonds.
SECURITY DOCUMENTS
Consents
Each of El Paso Merchant, Public Service Electric and El Paso entered into
a consent and agreement with the trustee and us whereby such party, among other
things, consented to the assignment to the trustee of all of its right, title,
interest and obligations under our material agreements to which it is a party
and agreed:
- to provide specified notifications to the trustee; and
- to not suspend (in the case of El Paso Merchant and El Paso) or terminate
the applicable agreement without providing the trustee or its designee
the opportunity to cure any default within 60 days (or within 30 days in
the case of the amended power purchase agreement) after the last day of
the cure period in the applicable agreement. Assignment by Public Service
Electric of its rights under the amended power purchase agreement is
prohibited without our consent unless the assignee is an entity with a
credit rating at least equivalent to Public Service Electric's rating
from both Moody's and Standard & Poor's. In addition, pursuant to the
consent and agreement with Public Service Electric, in the event that the
trustee or any designee or assignee succeeds to our interests under the
amended power purchase agreement, this successor will assume liability
for our obligations under the amended power purchase agreement, including
those obligations arising prior to succession.
Account Control Agreement
We entered into an account control agreement with the trustee and Bankers
Trust Company as security intermediary in order to perfect the trustee's
security interest in the security entitlements credited to the accounts and
pursuant to which Bankers Trust Company agrees to act as securities
intermediary.
PERFECTION OF SECURITY INTERESTS
The security interests granted under the financing documents will be
perfected to the extent that perfection may be obtained by filing financing
statements under the UCC and in the case of the securities entitlements credited
to the accounts, through the account control agreement.
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U.S. FEDERAL INCOME TAX CONSEQUENCES
UNITED STATES FEDERAL INCOME TAX
The following summary of federal income tax consequences has been prepared
by Chadbourne & Parke LLP. We urge you to consult your own tax advisors as to
the precise federal, state, local and other tax consequences of the exchange
offer.
The following discussion summarizes and represents the opinion of
Chadbourne & Parke LLP regarding the material United States federal income tax
consequences to beneficial owners arising from the exchange offer. The remainder
of this discussion generally refers to the Series A bonds and the Series B bonds
as the "bonds." The discussion which follows is based on the U.S. Internal
Revenue Code of 1986, as amended, the Treasury regulations promulgated
thereunder, and judicial and administrative interpretations thereof, all as in
effect on the date hereof, and is subject to any changes in these or other laws
occurring after such date, possibly with retroactive effect.
For purposes of this summary, the term "U.S. Holder" means a beneficial
owner of a bond that is, for U.S. federal income tax purposes, (a) an individual
who is a U.S. citizen or resident, (b) a corporation or partnership created or
organized under the laws of the United States or any political subdivision
thereof, or (c) an estate or trust that is otherwise subject to U.S. federal
income tax on a net basis with respect to its worldwide income. The term
"Non-U.S. Holder" means a beneficial owner of a bond who is not, for U.S.
federal income tax purposes, a U.S. Holder.
The discussion which follows is not intended as tax advice to any
particular investor. This summary is not a complete analysis or listing of all
potential U.S. federal income tax consequences to U.S. Holders and Non-U.S.
Holders relating to the bonds, and does not address the effect of any United
States gift, estate, state or local tax law or foreign tax law on a potential
investor in the bonds.
This summary is generally limited to investors who will hold the bonds as
"capital assets" within the meaning of Section 1221 of the Internal Revenue Code
and whose functional currency is the United States dollar. This summary does not
address the tax treatment of U.S. Holders and Non-U.S. Holders that may be
subject to special income tax rules such as insurance companies, tax-exempt
organizations, banks, U.S. Holders subject to the alternative minimum tax,
United States expatriates, holders that are broker-dealers in securities,
holders that own (directly, indirectly or by attribution) 10 percent or more of
our equity interests, or that hold the bonds as a hedge against currency risks,
as a position in a "straddle" for tax purposes, or as part of a conversion or
other integrated transaction.
Exchange Offer
The exchange of Series A bonds for Series B bonds pursuant to the exchange
offer will not constitute a taxable exchange for U.S. federal income tax
purposes. Accordingly, a U.S. Holder will not recognize gain or loss upon the
receipt of Series B bonds pursuant to the exchange offer, and a U.S. Holder will
be required to include interest on the Series B bonds in gross income in the
manner and to the extent interest income was includable under the Series A
bonds. A U.S. Holder's holding period for the Series B bonds will include the
holding period of the Series A bonds exchanged therefor, and such U.S. Holder's
adjusted basis in the Series B bonds will be the same as the basis of the Series
A bonds exchanged therefor immediately before the exchange.
U.S. Holders
Interest on the Bonds. Interest on a bond will be includable in the gross
income of a U.S. Holder as ordinary interest income at the time such interest is
treated as received or accrued, in accordance with the U.S. Holder's method of
accounting for U.S. federal income tax purposes. We expect that the bonds will
not be considered to be issued with original issue discount for U.S. federal
income tax purposes.
Make-Whole Premium. The bonds provide for the payment of additional
amounts under the circumstances described above under "Description of the
Bonds -- Payment of Principal and Interest,"
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and, therefore, are subject to the Treasury regulations that apply to debt
instruments that provide for one or more contingent payments. We believe that
the possible payment of such additional amounts would not cause the bonds to be
treated as having been issued with original issue discount under those Treasury
regulations, because, as of the issue date, the possibility of such payment is
"remote," and would therefore be ignored. In such circumstances, the rules
described above under "-- Interest on the Bonds" would apply. Our determination
that such payments are a remote contingency for these purposes is binding on a
U.S. Holder, unless such U.S. Holder discloses in the proper manner to the
Internal Revenue Service that it is taking a different position.
Market Discount. A U.S. Holder that purchases a bond at a market discount
(as described below) generally will be required to treat any principal payments
on, or any gain on the disposition or maturity of, such bond as ordinary income
to the extent of the accrued market discount (not previously included in income)
at the time of such payment or disposition. In general, market discount is the
amount by which the bond's stated redemption price at maturity exceeds the U.S.
Holder's basis in the bond immediately after the bond is acquired. A bond is not
treated as purchased at a market discount, however, if the market discount is
less than 0.25% of the stated redemption price at maturity of the bond
multiplied by the number of complete years to maturity from the date when the
U.S. Holder acquired the bond. Market discount on a bond will accrue on a
straight-line basis, unless the U.S. Holder elects to accrue such discount on a
constant yield to maturity basis. This election is irrevocable and applies only
to the bond for which it is made. The U.S. Holder may also elect to include
market discount in income currently as it accrues. This election, once made,
applies to all market discount obligations acquired on or after the first day of
the first taxable year to which the election applies and may not be revoked
without the consent of the IRS. Generally, if a bond with market discount is
transferred in specified non-taxable transactions (other than a non-recognition
transaction described in Section 1276(c) of the Code), accrued market discount
will be includable as ordinary income to the U.S. Holder as if such U.S. Holder
sold the bond at its fair market value. A U.S. Holder may be required to defer
until the maturity of the bond or, in some circumstances, its earlier
disposition, the deduction for all or a portion of the interest expense
attributable to debt incurred or continued to purchase or carry a bond with
market discount, unless an election to include the market discount on a current
basis is made.
Amortizable Bond Premium. A U.S. Holder that purchases a bond for an
amount in excess of its stated principal amount at maturity will generally be
considered to have purchased the bond with "amortizable bond premium." A U.S.
Holder generally may elect to amortize such premium using the constant yield to
maturity method. The amount amortized in any year will generally be treated as a
reduction of the U.S. Holder's interest income on the bond. The premium on a
bond held by a U.S. Holder that does not make such an election will decrease the
gain or increase the loss otherwise recognized on the sale, redemption,
retirement or other disposition of the bond. The election to amortize the
premium on a constant yield to maturity method, once made, applies to all debt
obligations held or subsequently acquired by the electing U.S. Holder on or
after the first day of the first taxable year to which the election applies and
may not be revoked without the consent of the IRS.
Disposition of the Bonds. In general, a U.S. Holder's adjusted tax basis
in a bond will equal the cost of such bond to the U.S. Holder, increased by the
amount of any market discount previously included in the U.S. Holder's income
with respect to the bond, and reduced by (i) the amount of any principal
payments on the bond and (ii) the amortized amount of any amortizable bond
premium on the bond.
A U.S. Holder will generally recognize gain or loss on the sale, retirement
or other disposition of a bond in an amount equal to the difference between (i)
the amount of cash and the fair market value of property received by such U.S.
Holder on such sale, retirement or other disposition (less any amounts
attributable to accrued but unpaid interest which will be taxable as such) and
(ii) the U.S. Holder's adjusted tax basis in the bond (as described above). Gain
or loss upon the sale, retirement or other disposition of a bond will be capital
gain or loss if the bond is a capital asset in the hands of the U.S. Holder and,
in the case of an individual U.S. Holder, will be subject to U.S. federal income
tax at a reduced rate if such bond was owned by such U.S. Holder for more than
one year. Gains on the sale of
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capital assets held for one year or less are subject to U.S. federal income tax
at ordinary income rates. Some limitations exist on the deductibility of capital
losses by both corporations and individual taxpayers.
Non-U.S. Holders
A Non-U.S. Holder of a bond generally will not be subject to U.S. federal
income tax by withholding or otherwise on the payment of interest (generally,
including stated interest and market discount, as adjusted by amortizable bond
premium) on a bond provided that the beneficial owner of the bond fulfills the
certification requirements set forth in applicable Treasury regulations unless
(A) such Non-U.S. Holder (i) actually or constructively owns 10% or more of the
total combined voting power of the equity of the Company entitled to vote, (ii)
is a controlled foreign corporation related, directly or indirectly, to the
Company through equity ownership or (iii) is a bank receiving interest described
in Section 881(c)(3)(A) of the Internal Revenue Code or (B) such interest is
effectively connected with the conduct of a trade or business by the Non-U.S.
Holder in the United States. Under these certification requirements, except as
described below, the last United States payer in the chain of payment prior to
payment to a Non-U.S. Holder (the "withholding agent") must have received in the
year in which a payment of principal, premium or interest occurs, or in either
of the two preceding calendar years, a statement that: (1) is signed by the
Non-U.S. Holder under penalties of perjury; (2) certifies that the holder is a
Non-U.S. Holder; and (3) provides the name and address of the Non-U.S. Holder.
The statement may be made on the appropriate U.S. Treasury Form W-8 (or on a
suitable substitute form), and the Non-U.S. Holder must inform the withholding
agent of any change in the information on the statement within 30 days of such
change. If the bonds are held through a securities clearing organization or some
other types of financial institutions that are not qualified intermediaries, the
organization or institution is required to provide its signed statement to the
withholding agent along with a copy of such Form W-8 (or suitable substitute
form) provided by the Non-U.S. Holder. If the bonds are held through a financial
institution that is a qualified intermediary, the qualified intermediary
generally will not be required to furnish a copy of the Form W-8 (or suitable
substitute form) received from the beneficial owner. A qualified intermediary is
a financial institution that has entered into a withholding agreement with the
IRS. If the bonds are held by a foreign complex trust, the trust is treated as
the beneficial owner. If the bonds are held through a foreign partnership, a
foreign simple trust or a foreign grantor trust, the partner, beneficiary or
grantor is treated as the beneficial owner, and the foreign partnership or
foreign trust must provide its signed statement to the withholding agent along
with a copy of the appropriate Form W-8 (or suitable substitute form) received
from the beneficial owner.
A Non-U.S. Holder generally will not be subject to United States federal
income tax by withholding or otherwise on gain realized on the sale, retirement
or other disposition of a bond, unless (i) such gain is effectively connected
with the conduct by such Non-U.S. Holder of a trade or business within the
United States, or (ii) such gain is realized by an individual Non-U.S. Holder
who is present in the United States for at least 183 days in the taxable year of
the sale, retirement or other disposition, and specified other conditions are
met.
UNITED STATES INFORMATION REPORTING AND BACKUP WITHHOLDING
Payments of principal, premium and interest and the proceeds from the
disposition by some non-corporate holders of bonds may be subject to U.S.
information reporting and backup withholding. A U.S. Holder generally will be
subject to U.S. information reporting and backup withholding at a rate of 31%
unless the U.S. Holder supplies an accurate taxpayer identification number, as
well as other information, or otherwise establishes, in the manner prescribed by
law, an exemption. U.S. information reporting and backup withholding may also
apply to Non-U.S. Holders that are not "exempt recipients" and that fail to
provide specified information as may be required by U.S. law and applicable
regulations. Any amount withheld under backup withholding is not an additional
tax and is generally allowable as a credit against the beneficial owner's
federal income tax upon furnishing the required information to the IRS.
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You should consult your own tax advisors regarding the application of the
U.S. information reporting and backup withholding rules to your particular
situation, including your qualification for exemption therefrom, and the
procedure for obtaining such an exemption, if applicable.
You should also consult your tax advisor as to the tax consequences of the
transaction and of owning the bonds in view of your particular situation.
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ERISA CONSIDERATIONS
If you intend to use plan assets to purchase any of the bonds offered for
sale in connection with 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,
and the prohibited transaction provisions of ERISA. If you intend to use
governmental or church plan assets to purchase any of the bonds, 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 Internal
Revenue 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 bond 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 bonds.
You should consider all factors and circumstances of a particular
investment in the bonds, 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
bonds.
We are not making any representation that the sale of any bonds 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 Internal Revenue Code prohibit a wide range of transactions
involving (1) employee benefit plans and arrangements subject to ERISA and/or
the Internal Revenue Code, and (2) persons who have specified relationships to
the plans. These persons are called "parties in interest" under ERISA and
"disqualified persons" under the Internal Revenue Code. The transactions
prohibited by ERISA and the Internal Revenue 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 Internal Revenue Code. As a
result, if you are considering using plan assets to invest in any of the bonds
offered for sale in connection with this prospectus, you should consider whether
the investment might be a prohibited transaction under ERISA and/or the Internal
Revenue Code.
Prohibited transactions may arise, for example, if the bonds 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 Internal Revenue Code may apply depending in part
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on the type of plan fiduciary making the decision to acquire a bond and the
circumstances under which such decision is made. Some of these exemptions
include:
(1) Prohibited transaction class exemption or "PTCE" exemptions 96-23,
(relating to specified transactions directed by in-house asset managers);
(2) PTCE 95-60 (relating to specified transactions involving insurance
company general accounts);
(3) PTCE 91-38 (relating to specified transactions by bank collective
investment funds);
(4) PTCE 90-1 (relating to specified transactions involving insurance
company pooled separate accounts);
(5) PTCE 84-14 (relating to specified transactions directed by
independent qualified professional asset managers); and
(6) PTCE 75-1 (relating to specified transactions involving employee
benefit plans and broker-dealers, reporting dealers and banks).
These exemptions do not, however, provide relief from the self-dealing
prohibitions under ERISA and the Internal Revenue 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 bonds.
TREATMENT OF BONDS AS DEBT INSTRUMENTS
Some transactions involving our operation could give rise to prohibited
transactions under ERISA and the Internal Revenue 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 Cedar Brakes I,
L.L.C., 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 bonds should be treated
as debt rather than equity interest under the plan assets regulations because
the bonds (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 bonds will be treated as debt for purposes of ERISA. If the bonds
were to be treated as an equity interest under the plan assets regulations, the
purchase of the bonds using plan assets could cause our assets to become subject
to the fiduciary and prohibited transaction provisions of ERISA and the Internal
Revenue Code unless investment in the bonds 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 bonds are treated as equity interests
under the plan asset regulations and investment in the bonds by benefit plan
investors is significant, our assets could be treated as the 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 bonds 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, 501
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.
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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 Internal Revenue Code, may be subject to state or
other federal laws that are very similar to the provisions of ERISA and the
Internal Revenue Code. If you are a fiduciary of a governmental or church plan,
you should consult with counsel before purchasing any bonds 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 bond offered
for sale in connection with this prospectus, you should consider whether the
acquisition, holding or disposition of a bond would satisfy such indicia of
ownership rules.
REPRESENTATIONS AND WARRANTIES
If you acquire or accept a bond 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 bond; or
(2) your acquisition and holding of a bond (A) is exempt from the
prohibited transaction restrictions of ERISA and the Internal Revenue Code
under one or more prohibited transaction class exemptions or does not
constitute a prohibited transaction under ERISA and the Internal Revenue
Code, and (B) meets the fiduciary requirements of ERISA.
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 Series B bonds
issued under the exchange offer in exchange for Series A bonds unless you are:
- our "affiliate" within the meaning of Rule 405 under the Securities Act;
- a broker-dealer that acquired Series A bonds directly from us; or
- a broker-dealer that acquired Series A bonds 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 Series B bonds 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 Series B bonds. Broker-dealers receiving Series B bonds in the exchange
offer will be subject to a prospectus delivery requirement with respect to
resales of the Series B bonds.
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 Series
A bonds, with the prospectus contained in the exchange offer registration
statement.
Pursuant to the Registration Agreement, each broker-dealer that receives
Series B bonds for its own account pursuant to the exchange offer must
acknowledge that it will deliver a prospectus in connection with any resale of
such Series B bonds. 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
Series B bonds received in exchange for Series A bonds where such Series A bonds
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
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make this prospectus, as amended or supplemented, available to any broker-dealer
for use in connection with any such resale. In addition, until [ ], 2001,
all dealers effecting transactions in the Series B Bonds may be required to
deliver a prospectus.
We will not receive any proceeds from any sale of Series B bonds by
broker-dealers. Series B bonds 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 Series B bonds 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 Series B bonds. Any broker-dealer
that resells Series B bonds 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 Series B bonds may be deemed to be an "underwriter" within
the meaning of the Securities Act and any profit on any such resale of Series B
bonds 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 bonds), other than
commissions or concessions of any brokers or dealers, and will indemnify the
holders of the bonds (including any broker-dealers) against specified
liabilities, including liabilities under the Securities Act.
LEGAL MATTERS
Our counsel, Chadbourne & Parke LLP, New York, New York, will issue an
opinion regarding the validity and binding obligation of the bonds and other
specified legal matters.
EXPERTS
The financial statements of Cedar Brakes I, L.L.C. as of December 31, 2000
and for the period from inception (March 3, 2000) to December 31, 2000 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.
Pace prepared the power services agreement assessment included as Annex A
to this prospectus. We include this report in this prospectus in reliance upon
Pace's authority as a consultant in evaluation of power markets and related
matters. You should read this report in its entirety for information contained
therein with respect to the PJM power market and the related matters discussed
therein.
AVAILABLE INFORMATION
We are filing with the SEC a registration statement on Form S-4 relating to
the Series B bonds. This prospectus is a part of the registration statement, but
the registration statement includes additional information and also includes
exhibits that are referenced in this prospectus. You can review a copy of the
registration statement through the SEC's "EDGAR" System (Electronic Data
Gathering, Analysis and Retrieval) that is available on the SEC's web site
(http://www.sec.gov).
After our registration statement becomes effective, we will be required to
file publicly specified information under the Securities Exchange Act of 1934,
as amended. All our public filings will also be available on EDGAR, including
annual and quarterly reports and other information. You may also read and copy
all of our public filings at the SEC's public reference room at 450 Fifth
Street, N.W.,
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Washington, D.C. 20549 or at their facilities in New York and Chicago. Please
call the SEC at (800) 732-0330 for further information on the operation of the
public reference rooms.
While we are not required to nor do we intend to send annual reports to the
holders of the bonds, we will be filing the reports required by the Securities
Exchange Act and copies of our filings with the SEC will be provided to the
trustee.
El Paso and Public Service Electric are subject to the information
requirements of the Securities Exchange Act, and, in accordance therewith, file
periodic reports, proxy statements and other information with the SEC.
Reports, proxy statements and other information filed by El Paso and Public
Service Electric with the SEC can be inspected, without charge, and copied at
the public reference facilities maintained by the SEC at 450 Fifth Street, N.W.,
Room 1024, Washington D.C. 20549 and at the SEC's regional offices at Citicorp
Center, 500 West Madison Street, Suite 1400, Chicago, Illinois 60661 and 7 World
Trade Center, Suite 1300, New York, New York 10048. The SEC also maintains a
site on the Internet at http://www.sec.gov that contains reports, proxies and
other information regarding registrants that file electronically with the SEC,
and other filings by El Paso and Public Service Electric are available at that
web site. Copies of such materials also can be obtained from the Public
Reference Section of the SEC at 450 Fifth Street, N.W., Washington, D.C. 20549
at prescribed rates.
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INDEX TO FINANCIAL STATEMENTS
PAGE
----
Report of Independent Accountants........................... F-2
Financial Statements:
Statement of Income....................................... F-3
Balance Sheet............................................. F-4
Statement of Cash Flows................................... F-5
Statement of Member's Capital............................. F-6
Notes to the Financial Statements........................... F-7
F-1
100
REPORT OF INDEPENDENT ACCOUNTANTS
To the Member of Cedar Brakes I, L.L.C.:
In our opinion, the accompanying balance sheet and the related statements
of income, of member's capital and of cash flows present fairly, in all material
respects, the financial position of Cedar Brakes I, L.L.C. (the "Company") at
December 31, 2000, and the results of its operations and its cash flows for the
period from inception (March 3, 2000) to December 31, 2000, in conformity with
accounting principles generally accepted in the United States of America. These
financial statements are the responsibility of the Company's management; our
responsibility is to express an opinion on these financial statements based on
our audit. We conducted our audit 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 audit provides a
reasonable basis for our opinion.
/s/ PricewaterhouseCoopers LLP
- ------------------------------------------------------
Houston, Texas
March 8, 2001
F-2
101
CEDAR BRAKES I, L.L.C.
STATEMENT OF INCOME
FOR THE PERIOD FROM INCEPTION (MARCH 3, 2000) TO DECEMBER 31, 2000
(IN THOUSANDS)
Operating revenues
Electricity sales......................................... $14,638
-------
Operating expenses
Electricity purchases..................................... 4,766
Administrative fees to affiliate.......................... 26
Amortization of power purchase agreement.................. 5,937
-------
10,729
-------
Operating income............................................ 3,909
-------
Other (income) expense
Interest income........................................... (14)
Interest and debt expense................................. 7,055
-------
7,041
-------
Net loss.................................................... $(3,132)
=======
See accompanying notes.
F-3
102
CEDAR BRAKES I, L.L.C.
BALANCE SHEET
AS OF DECEMBER 31, 2000
(IN THOUSANDS)
ASSETS
Current assets
Cash and cash equivalents................................. $ 8,692
Accounts receivable -- Public Service Electric............ 5,272
--------
Total current assets.............................. 13,964
Power purchase agreement, net............................... 283,893
Restricted cash............................................. 13,201
Deferred financing costs, net............................... 5,060
--------
Total assets...................................... $316,118
========
LIABILITIES AND MEMBER'S CAPITAL
Current liabilities
Accounts payable
Trade.................................................. $ 12
Affiliate.............................................. 1,743
Accrued interest payable.................................. 6,894
--------
Total current liabilities......................... 8,649
Long-term debt.............................................. 310,600
Commitments
Member's capital............................................ (3,131)
--------
Total liabilities and member's capital............ $316,118
========
See accompanying notes.
F-4
103
CEDAR BRAKES I, L.L.C.
STATEMENT OF CASH FLOWS
FOR THE PERIOD FROM INCEPTION (MARCH 3, 2000) TO DECEMBER 31, 2000
(IN THOUSANDS)
OPERATING ACTIVITIES
Net loss.................................................. $ (3,132)
Adjustments to reconcile net loss to net cash provided by
operating activities
Amortization of power purchase agreement............... 5,937
Amortization of deferred financing costs............... 161
Working capital changes
Accounts receivable -- Public Service Electric....... (5,272)
Accounts payable -- trade and affiliate.............. 1,755
Accrued interest payable............................. 6,894
---------
Net cash provided by operating activities......... 6,343
---------
INVESTING ACTIVITIES
Purchase of power purchase agreement...................... (289,830)
---------
Net cash used in investing activities............. (289,830)
---------
FINANCING ACTIVITIES
Net proceeds from issuance of long-term debt.............. 305,379
Initial capital contribution.............................. 1
Increase in restricted cash............................... (13,201)
---------
Net cash provided by financing activities......... 292,179
---------
NET CHANGE IN CASH AND CASH EQUIVALENTS..................... 8,692
CASH AND CASH EQUIVALENTS, beginning of period.............. --
---------
CASH AND CASH EQUIVALENTS, end of period.................... $ 8,692
=========
See accompanying notes.
F-5
104
CEDAR BRAKES I, L.L.C.
STATEMENT OF MEMBER'S CAPITAL
FOR THE PERIOD FROM INCEPTION (MARCH 3, 2000) TO DECEMBER 31, 2000
(IN THOUSANDS)
Initial capital contribution on March 3, 2000............... $ 1
Net loss.................................................... (3,132)
-------
Balance, December 31, 2000.................................. $(3,131)
=======
See accompanying notes.
F-6
105
CEDAR BRAKES I, L.L.C.
NOTES TO THE FINANCIAL STATEMENTS
1. ORGANIZATION AND NATURE OF OPERATIONS
We are a single member Delaware limited liability company organized in
March 2000, pursuant to the terms of a limited liability company agreement. We
are owned indirectly by Chaparral Investors, L.L.C. Chaparral is owned by
Limestone Electron Trust and El Paso Corporation and was established to own and
manage investments in power and natural gas assets within North America.
Chaparral indirectly owns interests in (i) twenty-two commercially operating
natural gas-fired power facilities in New Jersey, Rhode Island, Massachusetts,
Colorado, Nevada and California, and (ii) three natural gas-fired power
facilities under development and construction in Connecticut and Florida.
We began operations on September 27, 2000 when we acquired a long-term
power purchase agreement to sell electric capacity and electric energy to Public
Service Electric & Gas Company ("Public Service Electric"). We do not have any
employees and our operations are carried out by El Paso Merchant Energy, a
subsidiary of El Paso Corporation under a long-term administrative services
agreement (See Note 6). We purchase the electric capacity and energy necessary
to meet our obligations under our power purchase agreement from El Paso Merchant
under a long-term power services agreement (See Note 5).
2. LIMITED LIABILITY COMPANY
Under Delaware law, no member of a limited liability company is obligated
personally for any debt, obligation, or liability of a limited liability company
simply because they are a member of that limited liability company. Such debts,
liabilities and obligations are solely those of the limited liability company.
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
Our financial statements are prepared on the accrual basis of accounting in
conformity with accounting principles generally accepted in the United States.
Use of Estimates
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States requires us to make estimates
and assumptions that affect the reported amounts of assets, liabilities,
revenues and expenses and disclosure of contingent assets and liabilities that
exist at the date of the financial statements. Actual results are likely to
differ from those estimates.
Cash and Cash Equivalents
We consider short-term investments purchased with an original maturity of
three months or less to be cash equivalents.
Restricted Cash
As required by our bond indenture (See Note 4), we established a restricted
cash fund from the proceeds of our bond issuance equal to the amount of a
semi-annual interest payment. We must maintain this fund through the maturity
date of the bonds. As of December 31, 2000, we had restricted cash of $13.2
million.
Allowance for Doubtful Accounts
We review collectibility of our accounts receivable on a regular basis,
primarily under the specific identification method. At December 31, 2000, no
allowance for doubtful accounts was recorded.
F-7
106
Intangible Assets
Our intangible assets represent the fair value of a power purchase
agreement we acquired which we are amortizing ratably as we recognize revenue.
Amortization of intangible assets was approximately $5.9 million for the period
ended December 31, 2000. Beginning January 1, 2001, our power purchase agreement
will be accounted for as a derivative under the provisions of Statement of
Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities. See our discussion of Recent Accounting
Pronouncements below.
We evaluate the impairment of our intangibles in accordance with SFAS No.
121 Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets
to be Disposed Of. Under this methodology, when an event occurs to suggest that
an impairment may have occurred, we review the undiscounted net cash flows of
the underlying asset. If these cash flows are not sufficient to recover the
amount of the underlying asset on our books, these cash flows are discounted at
a risk-adjusted rate with the difference recorded as an impairment in the
statement of income. No impairments were recorded during the period ended
December 31, 2000.
Deferred Financing Costs
Our deferred financing costs represent the cost to issue our bonds and are
being amortized using the effective-interest method. Amortization of deferred
financing costs was approximately $161,000 for the period ended December 31,
2000.
Income Taxes
Since we are a limited liability company, income taxes accrue to our
member. As a result, we have not reflected a provision for income taxes in our
financial statements.
Revenue Recognition
We recognize revenue when we deliver electricity. Revenue is based on the
quantity of electricity delivered at rates specified under contractual terms.
Recent Accounting Pronouncements
In June 1998, the Financial Accounting Standards Board issued SFAS No. 133,
Accounting for Derivative Instruments and Hedging Activities. In June of 1999,
the FASB extended the adoption date of SFAS No. 133 through the issuance of SFAS
No. 137, Deferral of the Effective Date of FASB Statement No. 133. In June 2000,
the FASB issued SFAS No. 138, Accounting for Certain Derivative Instruments and
Certain Hedging Activities, which also amended SFAS No. 133. SFAS No. 133, and
its amendments and interpretations, establishes accounting and reporting
standards for derivative instruments, including certain derivative instruments
embedded in other contracts, and for hedging activities. It will require that we
measure all derivative instruments at their fair value, and classify them as
either assets or liabilities on our balance sheet, with a corresponding offset
to income or other comprehensive income depending on their designation, their
intended use, or their ability to qualify as hedges under the standard. We
adopted SFAS No. 133 on January 1, 2001, and applied the standard to all
derivative instruments that existed on that date, which included our amended
power purchase agreement and power services agreement.
The impact of adopting SFAS No. 133 resulted in an increase to our assets
and a credit to net income of approximately $89.4 million. This impact is based
upon the expected cash receipts (payments) derived from the power purchase
agreement and the power services agreement compared to our estimate of future
power prices in the respective market. Estimates of the future prices of power
are based on the forward pricing curve of the appropriate interconnect and this
curve is derived from actual prices observed in the market, price quotes from
brokers and extrapolation models. The effect of adopting SFAS No. 133 has been
classified as a cumulative effect of a change in accounting principle in our
2001 financial statements.
F-8
107
4. BONDS PAYABLE
In September 2000, we issued 8 1/2% Senior Secured Bonds (Series A bonds)
with an aggregate principal amount of $310.6 million. The bonds mature on
February 15, 2014, with principal paid annually on February 15 beginning in
2002. Interest payments are due semiannually on February 15 and August 15
beginning in 2001. The bonds are collateralized by our assets.
We have agreed to complete an offer to exchange the Series A bonds with
8 1/2% Series B Senior Secured Bonds due 2014 (Series B bonds) within 270 days
of the original issuance of the Series A bonds. The terms of the Series B bonds
and the Series A bonds are substantially the same in all material respects,
except that the Series B bonds will be registered with the SEC.
We may at any time redeem all or any portion of the outstanding bonds from
the holders at a redemption price equal to the principal amount plus accrued and
unpaid interest to the redemption date, plus a make-whole premium, if any. The
make-whole premium is equal to the discounted present value of all principal and
interest payments scheduled to become due after the redemption date less the
unpaid principal amount of the bonds, provided that the make-whole premium is
not less than zero.
We will be required to pay an additional 1/2% interest on our bonds if we
do not complete an exchange of our current bonds for bonds registered under the
rules of the SEC within 40 business days from the date on which a registration
statement has been declared effective by the SEC. El Paso Corporation is
obligated under a funding agreement entered into in September 2000 to contribute
to us an amount equal to the additional 1/2% interest on our bonds if, on the
third business day prior to any payment date, we do not have sufficient funds to
pay the additional interest due. This agreement terminates upon the consummation
of the exchange of our current bonds for bonds registered under the rules of the
SEC.
Obligations under our bonds are non-recourse to our member or any of its
affiliates, other than the payment of additional interest by El Paso Corporation
under its funding agreement.
The following are aggregate maturities of the principal amounts of our
bonds through maturity:
(IN
THOUSANDS)
2001........................................................ $ --
2002........................................................ 5,901
2003........................................................ 7,765
2004........................................................ 10,871
2005........................................................ 15,219
2006........................................................ 18,015
2007........................................................ 20,810
2008........................................................ 23,916
2009........................................................ 27,333
2010........................................................ 30,749
2011........................................................ 35,098
2012........................................................ 39,136
2013........................................................ 44,416
2014........................................................ 31,371
--------
Total bonds payable............................... $310,600
========
As required by our bond indenture, three separate cash accounts were
established from the proceeds of our bond issuance: the collections account, the
liquidity account and the damages and indemnity account. The collections account
was established to receive all payments that we are entitled to receive,
including revenues from energy and capacity sales to Public Service Electric
under the amended power purchase agreement. The liquidity account was
established to pay interest and principal due on the bonds in the event
sufficient funds are not available in the collections account and we are
required to maintain the cash amount necessary to make a payment equal to the
maximum amount of interest that will be due
F-9
108
on any single subsequent interest payment date. The damages and indemnity
account was established to receive all payments from El Paso Merchant under the
terms of the power services agreement (see Note 5) and El Paso Corporation under
the terms of the El Paso Corporation performance guaranty relating to damages by
us to Public Service Electric. These cash accounts are required to be maintained
for the life of the bond indenture. The balance in the liquidity account is
reported as restricted cash in the accompanying balance sheet.
5. COMMITMENTS
Power Purchase Agreement
In September 2000, we purchased a power purchase agreement from Newark Bay
for its fair market value of approximately $289.8 million. The power purchase
agreement has a term that extends through August 2013. We and Newark Bay are
indirect wholly-owned subsidiaries of Chaparral. Upon the acquisition of the
power purchase agreement, we successfully amended its terms with Public Service
Electric. Under the amended power purchase agreement, we are required to arrange
for energy capacity to be made available to Public Service Electric.
Additionally, we will sell and deliver energy at fixed rates to Public Service
Electric at specified delivery points, the annual deliveries of which cannot
exceed certain thresholds varying from 570,519 MWh to 855,779 MWh per year.
If we fail to provide all or part of the required energy capacity for
reasons other than a force majeure event or system emergency, Public Service
Electric must use reasonable efforts to purchase replacement capacity in the
amount of the shortfall. We must reimburse Public Service Electric for all costs
associated with the replacement capacity. If Public Service Electric is unable
to replace this capacity shortfall, Public Service Electric's payment to us will
be reduced by a credit as specified in the amended power purchase agreement.
Generally, the credit would equal the excess of the average market marginal
hourly price, if any, over the price as stated in our power purchase agreement
for those hours in which the shortfall occurred.
If we fail to deliver all or part of the scheduled energy or fail to
schedule sufficient deliveries to meet the minimum energy deliveries for reasons
other than a force majeure event or a system emergency, Public Service
Electric's payment to us will be reduced by a credit as specified in the amended
power purchase agreement. Generally the credit would equal the excess price
paid, if any, for energy by Public Service Electric over the price as stated in
our power purchase agreement.
Power Services Agreement
In September 2000, we entered into a power services agreement to purchase
power from El Paso Merchant at various fixed prices each year through August
2013. We are required to purchase 123 MW of energy capacity from El Paso
Merchant throughout the term of the contract. We are not required to purchase a
specific quantity of energy from El Paso Merchant, but we have the option to
purchase energy, the annual deliveries of which cannot exceed corresponding
thresholds as described in the amended power purchase agreement. All energy
purchased under this agreement will be supplied to Public Service Electric, and
only the amount requested by Public Service Electric will be purchased. El Paso
Merchant's performance under this agreement has been guaranteed by El Paso
Corporation under a performance guaranty issued in September, 2000.
If El Paso Merchant fails to deliver all or part of the scheduled energy to
us, for any reason other than a force majeure event or a system emergency, our
payment to El Paso Merchant will be reduced by a credit calculated in the same
manner as the credit to Public Service Electric described in the amended power
purchase agreement. If El Paso Merchant fails in any month to provide all or
part of the capacity, for any reason other than a force majeure event or a
system emergency, our payment to El Paso Merchant will be reduced by a credit
calculated in the same manner as the credit to Public Service Electric as a
direct result of our failure to provide capacity under the amended power
purchase agreement.
F-10
109
6. RELATED PARTY TRANSACTIONS
Administrative Services Agreement
In September 2000, we entered into an administrative services agreement
with El Paso Merchant to provide project management, finance and accounting
services to us for a fee of $100,000 per year through 2013. In addition to the
base fee, we are obligated to reimburse El Paso Merchant for certain direct
expenses other than project management, finance and accounting services that may
be incurred on our behalf. Fees and expenses under this agreement are due and
payable only to the extent that we have sufficient cash after paying obligations
under our bond indenture.
Affiliated Accounts Payable
Affiliated accounts payable represents the liability for energy purchased
by us from El Paso Merchant for the period from December 1, 2000 to December 31,
2000. Also included in affiliated accounts payable are administrative service
fees due to El Paso Merchant for the period from September 26, 2000 to December
31, 2000.
See Note 5 for additional discussion on commitments with related parties.
7. CONCENTRATION OF CREDIT RISKS
Our cash and accounts receivable potentially subject us to credit risk. Our
cash accounts are held by major financial institutions. Our trade receivables
and revenues are solely from a single customer, Public Service Electric, which
purchases electricity from us under a long-term power purchase agreement.
8. FAIR VALUE OF FINANCIAL INSTRUMENTS
As of December 31, 2000, the carrying amounts of our financial instruments
including cash, cash equivalents, and trade receivables and payables are
representative of fair value because of their short-term maturity. The carrying
amount and fair value of our long-term debt was $310.6 million at December 31,
2000. The fair value of our long-term debt has been estimated based on quoted
market prices for the same or similar issues.
F-11
110
[PACE LETTERHEAD]
ANNEX A
CEDAR BRAKES I, L.L.C.
POWER SERVICES AGREEMENT ASSESSMENT
PREPARED FOR:
CREDIT SUISSE FIRST BOSTON
September 20, 2000
Legal Notice
This Report was produced by Pace Global Energy Services, LLC ("Pace") and is
meant to be read as a whole and in conjunction with this disclaimer. Any use of
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on information obtained from various sources. While Pace believes such
information to be accurate, it makes no assurances, endorsements or warranties,
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respect to such use, actions or reliance.
This Report does contain some forward-looking opinions. Certain unanticipated
factors could cause actual results to differ from the opinions contained herein.
Forward-looking opinions are based on historical and/or current information that
relate to future operations, strategies, financial results or other
developments. Some of the unanticipated factors, among others, that could cause
the actual results to differ include regulatory developments, technological
changes, competitive conditions, new products, general economic conditions,
changes in tax laws, adequacy of reserves, credit and other risks associated
with Cedar Brakes I, L.L.C. and/or other third parties, significant changes in
interest rates and fluctuations in foreign currency exchange rates. Further,
certain statements, findings and conclusions in this report are based on Pace's
interpretations of various contracts. Contract interpretation of these contracts
by legal counsel or a jurisdictional body could differ.
Finally, this Report was prepared in June 2000 and is based on 2nd Quarter Year
2000 data for fuel and electric power prices. To the best of Pace's knowledge,
since the date of preparation of the Report, no event affecting the Report or
the matters referred to herein has occurred which changes in any material
adverse respect, as of the date hereof, any finding or conclusion contained in
the Report.
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TABLE OF CONTENTS
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Executive Summary........................................... A-1
Transaction Summary....................................... A-1
Scope of Work............................................. A-1
Summary of Analysis....................................... A-1
Findings and Conclusions.................................. A-3
Transaction Overview........................................ A-6
Transaction Overview...................................... A-6
Capacity and Energy Delivery Requirements................. A-7
Bid Strategy and Option Value Analysis...................... A-9
Introduction.............................................. A-9
Bid Strategy Analysis..................................... A-10
Option Value Analysis..................................... A-12
PJM Market Price Forecast................................... A-14
Market Clearing Price Forecast Approach................... A-14
Approach.................................................. A-14
Simulated Market Price Forecast For PJM................... A-15
CEMAS Simulated Market Prices.......................... A-15
Average System Annual Time of Day Prices............... A-16
Adjusted Average System Annual Time of Day Prices...... A-16
Wholesale Market Transactions............................. A-17
Existing Demand Profile................................... A-18
Base Case Assumptions..................................... A-20
Regional Market Definition and Transmission
Interchange.......................................... A-21
Regional Demand Forecast............................... A-22
Fuel Pricing........................................... A-27
Existing Generating Capacity Profiles.................. A-39
Expansion Generating Capacity.......................... A-41
Pace Global Energy Services, LLC............................ A-45
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EXHIBITS
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Exhibit 1: Relationship of EPM Contract Price to Market Price.......... A-3
Exhibit 2: Summary of the Average Hourly "All-In" Power Prices ($/MWh)
for the PSA Contract, Pace's Forward Price Curve Forecast,
Pace's Forecasted Option Value-Adjusted Price and Pace's
Forecasted Bid Strategy-Adjusted Price...................... A-4
Exhibit 3: Summary Overview of the Cedar Brakes Transaction............ A-7
Exhibit 4: PSE&G Contracted Annual Energy Delivery Requirements in
MWh......................................................... A-8
Exhibit 5: Average All Hour All-In Power Prices for the PJM Market for
the May 1, 1999 through April 30, 2000...................... A-10
Exhibit 6: Average All Hour All-In Power Price and its Standard
Deviation as a Function of The Total Available Days Per Year
in the PJM Market........................................... A-11
Exhibit 7: Relationship of EPM Contract Price to Market Price.......... A-12
Exhibit 8: Summary of the Average All Hour "All-In" Power Prices
($/MWh) for the EPM Contact and Forecasted Option Value
Adjusted Values............................................. A-13
Exhibit 9: Pace CEMAS Methodology...................................... A-15
Exhibit 10: PJM Northeast Annual System Time of Day Prices -- Base Case
(1998 $/MWh)................................................ A-16
Exhibit 11: PJM Average Annual EPM Contact and Bid Strategy Prices (1998
$/MWh)...................................................... A-17
Exhibit 12: Power Marketer Transactions by NERC Region.................. A-18
Exhibit 13: PJM Demand and Energy Requirements Forecast................. A-19
Exhibit 14: PJM Market Demand and Reserve Margin Forecast -- Summer..... A-20
Exhibit 15: PJM Market Demand and Reserve Margin Forecast -- Winter..... A-20
Exhibit 16: PJM Sub-Regional Designations............................... A-21
Exhibit 17: Assumed PJM Market Area Transmission Constraints............ A-22
Exhibit 18: Historic Inter-Regional Transactions........................ A-22
Exhibit 19: Pace Load Forecasting Methodology........................... A-23
Exhibit 20: Pace PJM Energy Forecast -- GWh............................. A-25
Exhibit 21: Pace PJM Energy Forecast -- GWh............................. A-25
Exhibit 22: Pace Sub-Regional Energy Forecast for PJM -- GWh............ A-26
Exhibit 23: Pace Sub-Regional Peak Demand Forecast for PJM -- MW........ A-27
Exhibit 24: Monthly Fuel Price Adjustment Factors....................... A-28
Exhibit 25: PJM Natural Gas Price Forecasts (1998 $/MMBtu).............. A-29
Exhibit 26: Pace Gas Price Sub-regions -- PJM........................... A-30
Exhibit 27: WTI Crude Oil Price Forecast (1998 $/MMBtu)................. A-32
Exhibit 28: Pace Oil Price Sub-Regions for PJM.......................... A-33
Exhibit 29: PJM Fuel Oil Location Basis (1998 $/MMBtu).................. A-33
Exhibit 30: Crude Oil to Refined Product Crack Spreads (1998 $/MMBtu)... A-34
Exhibit 31: Fuel Oil Price Forecast by PJM Sub-Region (1998 $/MMBtu).... A-34
Exhibit 32: Definition of Coal Quality Grades........................... A-35
Exhibit 33: Coal Consumption By Sulfur Grade -- PJM..................... A-37
Exhibit 34: Projected Real Commodity Escalation Rates by Sulfur Level... A-37
Exhibit 35: Projected Average Transportation Escalation Rates........... A-38
Exhibit 36: Avg. Delivered Coal Price Forecast For PJM by Sulfur Grade
(1998 $).................................................... A-39
Exhibit 37: PJM Nuclear Units........................................... A-40
Exhibit 38: Announced Power Projects in PJM............................. A-42
Exhibit 39: Expansion Unit Characteristics.............................. A-43
Exhibit 40: High Construction Cost Areas................................ A-44
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EXECUTIVE SUMMARY
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TRANSACTION SUMMARY
Cedar Brakes I, L.L.C. ("Cedar Brakes" or the "Issuer") has entered into an
Amended and Restated Power Purchase Agreement ("Amended and Restated PPA") with
Public Service Electric and Gas Company ("PSE&G"), which resulted from a
restructuring of the power purchase agreement ("Original PPA") entered into on
June 15, 1998, between the Newark Bay Cogeneration Partnership L.P. ("NBCP") and
PSE&G. The Amended and Restated PPA resulted in, among other things,
significantly reduced capacity and energy rates payable by PSE&G and
significantly more flexibility for Cedar Brakes to meet its energy and capacity
delivery obligations to PSE&G from any reliable source, not just a single power
plant.
In order to meet the 13-year power supply obligations to PSE&G under the Amended
and Restated PPA, Cedar Brakes entered into a Power Services Agreement ("PSA")
with El Paso Merchant Energy L.P. ("EPM") for the purchase of an equal amount of
capacity and energy, transferring its energy supply obligations under the
Amended and Restated PPA to EPM. El Paso Energy Corporation ("EPEC") has
ownership interests in Cedar Brakes, NBCP and EPM. Aside from energy rates, the
terms of the PSA mirror those of the Amended and Restated PPA, thus providing
EPM with the flexibility to supply energy and capacity from numerous sources
within the PJM market for delivery to Cedar Brakes, and from Cedar Brakes to
PSE&G. This flexibility in both the source and timing of energy delivery creates
significant option value to EPM. As such, the energy rates in the PSA, which
represent the option-value adjusted forecast of the PJM market, are
significantly lower than the energy rates in the Amended and Restated PPA. The
contract price differential represents the net revenue stream that is being
securitized in the bond offering.
SCOPE OF WORK
Pace Global Energy Services, LLC ("Pace"), an independent energy consulting
firm, was retained to review the PJM power market and certain provisions of the
PSA. Specifically, Pace was asked to provide an opinion as to whether (1) the
"all-in" energy and capacity prices under the PSA reasonably reflect market
pricing in the PJM region, adjusted for energy delivery flexibility ("option
value") that EPM has under the PSA, and whether (2) capacity resources within
the PJM market are sufficient to ensure that EPM can meet its contractual
obligations under the PSA. Our opinions assume that there will be no significant
changes to the PJM market with respect to the bidding process, the current cap
on bid prices and the market structure. Further, the analysis assumes there are
no adverse effects from EPM's other activities affecting its ability to perform
under the PSA with Cedar Brakes.
SUMMARY OF ANALYSIS
In order to provide an opinion as to the reasonableness of the annual PSA
contract prices, in conjunction with forecasting the PJM market clearing prices
over the term of the PSA, Pace performed two distinct analyses: a bid strategy
analysis and an option value analysis. The bid strategy analysis assesses the
potential value to EPM of selling power into the PJM market during hours when
EPM is not obligated to sell power to Cedar Brakes under the PSA. This analysis
includes a forecast of the market clearing prices during the hours in which EPM
would deliver energy under the PSA, assuming EPM fulfills its contractual
obligations during the lowest priced hours available. This forecast of PJM East
power prices is based on Pace's Capacity & Energy Market Analysis System
("CEMAS") model. CEMAS is an integrated resource planning tool designed to
simulate the deregulated power generation market and to project market clearing
prices for both capacity and
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energy under a defined set of assumptions. The option value analysis quantifies
the value to EPM derived from the delivery flexibility provided for in the PSA.
This analysis is a more conservative approach to valuing the energy delivery
flexibility contained in the PSA, as compared to the bid strategy analysis.
These analyses were performed in order to assess the value of the energy
delivery flexibility contained in the PSA.
THE BID STRATEGY ANALYSIS
The bid strategy analysis assessed the energy delivery flexibility in the PSA
that allows EPM to direct on a daily basis power deliveries, within contract
limits, to either the Cedar Brakes contract or to the PJM market. This analysis
was based on a strategy that would minimize the all-in cost to EPM of
electricity delivered under the PSA. By utilizing its contractual flexibility on
a daily basis EPM can, with fairly high certainty, sell power during the higher
priced days in the PJM market, while delivering the balance of its energy
delivery obligations to Cedar Brakes during lower priced periods. As such,
within certain limitations under the PSA, EPM can designate periods for selling
a substantial portion of its energy for its own account into the PJM market.
Although there are a limited number of days under the PSA for EPM to make sales
into the PJM market, the number of days available are sufficient to extract
substantial value from the PJM all-in annual average market price.
The PSA allows EPM to suspend energy deliveries to Cedar Brakes for
approximately five days per month or 23% of the time during the on-peak summer
period, assuming a 150 MWh delivery rate to PSE&G. EPM has a financial incentive
to suspend deliveries on days when power prices are highest in the PJM market,
which effectively lowers the cost of supplying energy under the PSA and supports
the below market contract price. Historical data have shown at least five days
per month when the market price rises considerably higher than the monthly
average. As EPM suspends delivery to Cedar Brakes during these days, the average
all-in cost to EPM of energy delivered during the month will correspondingly
decrease. In the off-peak and the non-summer on-peak periods, the number of days
when EPM can suspend delivery under the PSA increases significantly to 43% and
44%, respectively.
THE OPTION VALUE ANALYSIS
The option value analysis quantifies the value to EPM of the flexibility
embedded within the PSA by quantifying market priced option premiums via the use
of implied market volatility for options contracts traded in the PJM region. The
time-of-delivery flexibility provided in the PSA creates option value for EPM
that effectively depresses its all-in cost of energy relative to average market
prices in two ways. First, the potential for downward price movements in the
market will enable EPM to extract volatility value by selectively selling
(putting) energy to Cedar Brakes under the PSA at prices below forecasted market
levels. This "price-drop" value has been calculated by quantifying the monthly
put option premium in the PJM market. Second, as stated earlier, the potential
for price spikes in the summer peak periods will enable EPM to reduce the cost
of power delivered under the PSA by exercising its option to suspend energy
deliveries to Cedar Brakes for five days per month or approximately 23% of the
time during the on-peak summer period. This value has been quantified by summing
the value of the calculated premium derived from the sale of one-day power call
options that could be sold during approximately five days of each summer month.
These options effectively allow EPM to extract a portion of the highest energy
prices of the year for its own account (i.e., quantifying the value of not
supplying power when the market is hyper-inflated), thus, lowering the average
monthly all-in energy cost for energy sold under the PSA.
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Exhibit 1 illustrates the general relationship of PJM market prices to the
contract price under the PSA using the option value adjustment methodology. As
shown in Exhibit 1, contract price is equal to the average hourly annual market
price reduced by the value for the sale of on-peak call and put options and
off-peak put options.
EXHIBIT 1: RELATIONSHIP OF EPM CONTRACT PRICE TO MARKET PRICE
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FINDINGS AND CONCLUSIONS
Certain statements in this report are forward-looking and are based on current
assumptions and forecasts, and consequently involve risks and uncertainties.
Accordingly, the EPM's actual results could differ materially from the
expectations expressed in the forward-looking statements. While Pace believes,
based on its present knowledge and expertise, that the assumptions and forecasts
relied upon in this report are reasonable, given the uncertainties of energy
pricing, investors' review should include consideration of alternate assumptions
and forecasts.(1)
Pace has reviewed the PJM market as well as the PSA contract prices provided by
EPM in conjunction with the analyses described above. Our analysis focuses on
whether or not the contract prices provided by EPM are reasonable in light of
the current market structure, future expectations for the PJM market and the
energy delivery flexibility in the PSA. With respect to the PJM market review
and the PSA contract prices provided by EPM, Pace makes the following findings
and conclusions:
1. PJM operates a competitive wholesale energy market and facilitates open
access to transmission. With over 170 members including every segment of the
electric power industry, the PJM market has become one of the most liquid and
active energy markets in the country.
2. As of 1998, there were 52,000 MW of existing capacity present in the PJM
power market. The contract capacity specified in the PSA of approximately 123
MW represents approximately 0.2%-0.3% of the total existing capacity in this
market. The low market share coupled with a well-developed and highly
reliable electrical transmission system, capable of transferring high
quantities of power between generators/sellers and buyers, will allow EPM to
access numerous power purchasers for capacity and energy sales and purchases.
EPM will therefore have many options to fulfill its on-peak and off-peak
obligations under the PSA and exploit the energy delivery flexibility of the
PSA. There may be times when the PJM electric transmission system may
experience disruptions due to system component failures or act-of-god events.
However, these events are highly unlikely to affect EPM's overall ability to
fulfill its on-peak and off-peak obligations under the PSA, given the design
and overall size of the PJM transmission system as well as the makeup energy
provisions in the PSA.
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1 Please note that this Report was prepared in June 2000 and is based on 2nd
Quarter Year 2000 data for fuel and electric power prices. To the best of
Pace's knowledge, since the date of preparation of the Report, no event
affecting the Report or the matters referred to herein has occurred which
changes in any material adverse respect, as of the date hereof, any finding or
conclusion contained in the Report
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3. Incremental capacity is needed in the region to match energy demand growth,
which is estimated to average 1.64% per year over the term of the 13-year
contract based on PJM forecasts and similar forecasts conducted by Pace.
4. Given the structure of the PSA, EPM has the flexibility to sell to the market
during volatile peak periods and conversely put power to Cedar Brakes during
lower pricing periods. The implicit capacity factor based on contracted
energy delivery requirements of the PSA is 77% during summer peak hours and
56% during non-summer peak periods. The implicit capacity factor based on
contract delivery quantities during non-peak periods is 57%.
5. Based on the scheduling flexibility in the PSA and imputing the PJM market
price by eliminating the volatile peak periods, the average projected market
price is $22.09/MWh under the bid strategy analysis and $20.63/MWh under the
option value analysis, in East PJM for the September through December 2000
period.
6. As illustrated in Exhibit 2, for the 2001 through 2006 period, Pace believes
the PSA contract price is in-line with Pace's adjusted market price. For the
remainder of the forecast period (2007-2013), Pace estimates that the
contract prices under the PSA are slightly lower than Pace's adjusted market
price. However, given the increasing level of uncertainty as the time horizon
becomes more distant, Pace believes that the contract prices are not
significantly different from market expectations. Accordingly, on a net
present value ("NPV") basis, the value ascribed to the differential between
the Pace-adjusted market prices and the PSA contract prices is approximately
4%, assuming a discount rate of 10% and a 13-year term of the PSA.
EXHIBIT 2: SUMMARY OF THE AVERAGE HOURLY "ALL-IN" POWER PRICES ($/MWh) FOR
THE PSA CONTRACT, PACE'S FORWARD PRICE CURVE FORECAST, PACE'S FORECASTED OPTION
VALUE-ADJUSTED PRICE AND PACE'S FORECASTED BID STRATEGY-ADJUSTED PRICE
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PSA CONTRACT PACE'S FORWARD
PRICES PROVIDED PRICE CURVE OPTION VALUE BID STRATEGY
YEAR BY EPM FORECAST ADJUSTED PRICES ADJUSTED PRICES
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2000(1) 23.03 23.37 20.63 22.09
2001 29.71 35.42 30.25 27.56
2002 29.30 33.84 29.19 26.40
2003 28.56 32.57 27.87 25.32
2004 27.94 33.94 28.47 26.46
2005 28.07 34.21 28.63 26.68
2006 28.26 34.93 29.37 27.26
2007 28.26 36.37 30.48 28.38
2008 28.80 37.03 31.21 28.94
2009 29.08 38.39 32.23 30.10
2010 29.36 39.61 33.26 31.06
2011 29.64 40.90 34.30 32.12
2012 29.94 42.29 35.26 33.25
2013(1) 33.75 50.99 41.83 34.21
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(1) These prices have been adjusted to reflect the timing and term of the bond
offering.
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Based upon Pace's analysis of the PJM power market and a review of the relevant
portions of the Cedar Brakes transaction documents, we believe that the contract
rates stipulated in the PSA reasonably reflect market prices in the PJM market,
adjusted for the energy delivery flexibility ("option value") that EPM has under
the PSA. Moreover, we believe that the PJM market offers sufficient power
resources to enable EPM to meet its contractual obligations under the PSA.
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TRANSACTION OVERVIEW
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TRANSACTION OVERVIEW
NBCP owns a 147 megawatt ("MW") cogeneration facility located in Newark, New
Jersey ("the Facility"). Pursuant to the Original PPA with PSE&G, NBCP sold
generation capacity and the associated energy from the Facility to PSE&G. The
Original PPA was acquired and subsequently amended and restated in its entirety
by PSE&G and Cedar Brakes. Under the Amended and Restated PPA, the capacity and
energy rates paid by PSE&G have been significantly reduced from those under the
original PPA, while Cedar Brakes, as seller, has been given significantly more
flexibility in scheduling deliveries, including the right to select the source
of energy and capacity from which to meet its delivery obligations. This
scheduling and source flexibility significantly enhances the economic value of
the Amended and Restated PPA to Cedar Brakes.
Exhibit 3 below provides a summary of the Cedar Brakes transaction. The proceeds
of the bond offering will be used to purchase the Original PPA, cover certain
transaction costs and fund the liquidity account. The contract prices under the
PSA and the Amended and Restated PPA allow Cedar Brakes to realize a spread on
its energy sales in order to service the debt. As depicted, Cedar Brakes
supplies the energy and capacity requirements, as stipulated in the Amended and
Restated PPA, in return for energy and capacity payments from PSE&G. The
interest and principal on the bonds will be paid solely from capacity and energy
payments from PSE&G (as supplemented, under certain circumstances, by funds in a
liquidity account). Net of the costs of capacity and energy purchased from EPM
under the PSA, all scheduled payments of principal and interest on the bonds
have been calculated based on the net annual capacity and energy revenues.
In order to meet its obligations under the Amended and Restated PPA, Cedar
Brakes entered into the PSA with EPM. The PSA mirrors the terms and conditions
in the Amended and Restated PPA with the exception of the hourly price per
megawatt hour, which is significantly lower. Under the PSA, EPM will supply the
capacity and energy required by Cedar Brakes to meet its energy delivery
obligations under the Amended and Restated PPA. The PSA also provides payment of
liquidated damages and indemnification of Cedar Brakes in the event of energy
delivery shortfalls, i.e., failure to meet the capacity and energy delivery
requirements. Cedar Brakes has also entered into an Administrative Services
Agreement with EPM pursuant to which EPM carries out all of Cedar Brakes
administrative affairs and contractual obligations, including those under the
Amended and Restated PPA. Lastly, EPEC has provided an unconditional guarantee
of all payment and performance obligations of EPM under the PSA and
Administrative Services Agreement.
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EXHIBIT 3: SUMMARY OVERVIEW OF THE CEDAR BRAKES TRANSACTION
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[CHART]
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CAPACITY AND ENERGY DELIVERY REQUIREMENTS
Presented below are the terms and conditions of the PSA that were relevant to
Pace's analysis:
a) The PSA becomes effective on the later of (i) the last date upon which
certain conditions precedent are satisfied or waived and (ii) September
4, 2000, and remains in effect through and including August 31, 2013
unless terminated earlier as provided in the PSA.
b) EPM has the option to supply Cedar Brakes' capacity and energy
requirements from any source in the PJM market, including but not
limited to the NBCP Facility.
c) EPM is required to take all necessary steps for PSE&G to receive at
least 123 MW of capacity credits per day from the PJM market, including
utilizing PJM's "eCapacity" mechanism throughout the term of the PSA.
d) EPM is required to deliver energy to Cedar Brakes according to the
annual contracted levels presented in Exhibit 4.
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EXHIBIT 4: PSE&G CONTRACTED ANNUAL ENERGY DELIVERY REQUIREMENTS IN MWh
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GROSS ANNUAL ON-PEAK OFF-PEAK
YEAR ENERGY DELIVERIES DELIVERIES DELIVERIES
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2000 788,954 394,000 394,954
2001 788,954 394,000 394,954
2002 788,954 394,000 394,954
2003 811,229 394,000 417,229
2004 855,779 394,000 461,779
2005 855,779 394,000 461,779
2006 855,779 394,000 461,779
2007 855,779 394,000 461,779
2008 855,779 394,000 461,779
2009 855,779 394,000 461,779
2010 855,779 394,000 461,779
2011 855,779 394,000 461,779
2012 855,779 394,000 461,779
2013 570,519 394,000 176,519
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e) EPM may deliver energy at a rate of up to 150 MWh per hour unless EPM is
also scheduling "make-up energy", in which case EPM may deliver up to
200 MWh per hour.
f) EPM must schedule and deliver energy at the same rate during all on-peak
hours in any day and at the same rate during off-peak hours in any day.
However, the delivery rate for on-peak hours in a given day may differ
from the delivery rate for off-peak hours in the same day and the
delivery rate for on-peak and off-peak hours may vary from day to day.
g) During the on-peak summer period of June, July, August and September,
EPM must deliver to Cedar Brakes at least 40,000 MWh per month during
the on-peak hours. For the remaining eight months of the year (on-peak
non-summer period), EPM must deliver an aggregate of 234,000 MWh during
the on-peak hours.
h) EPM must deliver aggregate energy during the off-peak hours as noted in
Exhibit 4.
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BID STRATEGY AND OPTION VALUE ANALYSIS
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INTRODUCTION
In order to determine whether the contract prices contained in the PSA are
reasonable, in conjunction with forecasting the PJM market clearing prices over
the term of the PSA, Pace performed two distinct analyses: a bid strategy
analysis and option value analysis. The bid strategy analysis assesses the
potential value to EPM of selling power into the PJM market during hours when
EPM is not obligated to sell power to Cedar Brakes under the PSA. This analysis
includes a forecast of the market clearing prices during the hours in which EPM
would deliver energy under the PSA, assuming EPM fulfills its contractual
obligations during the lowest priced hours available. This forecast of PJM East
power prices is based on Pace's Capacity & Energy Market Analysis System
("CEMAS") model. CEMAS is an integrated resource- planning tool designed to
simulate the deregulated power generation market and to project market clearing
prices for both capacity and energy under a defined set of assumptions. The
option value analysis quantifies the value to EPM in the options market derived
from the delivery flexibility provided for in the PSA. This analysis is a more
conservative approach to valuing the energy delivery flexibility as compared to
the bid strategy analysis. These analyses were performed in order to assess the
value of the energy delivery flexibility contained in the PSA.
Exhibit 5 illustrates the PJM market price volatility associated with all-in
power prices for the May 1, 1999 through April 30, 2000 period. In general, the
summer months possess the greatest price volatility. This is apparent from the
price spike levels as compared to the annual average all-in power prices.
Although this is an historical perspective on the PJM energy market, we expect
similar behavior in the future, barring any major structural changes to the PJM
market. Therefore, we believe the conclusions based on the historical PJM market
data are relevant.
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EXHIBIT 5: AVERAGE ALL HOUR ALL-IN POWER PRICES FOR THE PJM MARKET FOR THE
MAY 1, 1999 THROUGH APRIL 30, 2000
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[CHART]
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BID STRATEGY ANALYSIS
The bid strategy analysis assessed the energy delivery flexibility in the PSA
that allows EPM to control the scheduling of certain power deliveries on a daily
basis. This analysis was based on a strategy that would minimize the all-in cost
to EPM of electricity delivered under the PSA. By utilizing the contractual
flexibility on a daily basis, EPM can, with fairly high certainty, select days
to sell its power in the higher priced PJM market, while delivering the balance
of its energy to Cedar Brakes to meet its contractual obligations under the PSA.
As such, within certain limitations under the PSA, EPM can designate periods for
selling a substantial portion of its energy into the PJM market. Although there
are a limited number of days under the PSA for EPM to make sales into the PJM
market, the number of days available are sufficient to extract substantial value
from the PJM all-in annual average market price.
Based on historical data, we would expect at least five days per month when
the average peak power price rises considerably higher than the average monthly
peak price. This market feature will afford EPM opportunities to lower its total
cost of energy deliveries under the PSA by selectively omitting these days for
delivery. The amount of delivery flexibility in the PSA is the highest in the
off-peak and non-summer peak periods, during which time EPM can choose to
suspend energy deliveries for approximately 45% of the total hours. During the
summer on-peak period, EPM can suspend energy deliveries for about 23% of the
total available peak hours.
It would be unreasonable to assume that EPM would be able to designate all of
the high price days available in any one month. However, it is reasonable to
assume that EPM would be fairly successful given the number of
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days of energy delivery flexibility and the nature of the PJM power market.
Accordingly, a max-min volatility valuation was structured to reflect the power
market trading risk and the embedded optionality contained in the PSA.
Exhibit 6 illustrates the average annual all-in power price and its standard
deviation as a function of the total number of the highest priced days per year
excluded in the calculation. The X-axis measures the number of days excluded as
a percentage of the total number of days per year. The Y-axis measures the
average annual all-in power prices in dollars per MWh. One hundred percent
represents the average based on 365 days and 80% represents 292 days and so on.
Based on our analysis, eliminating approximately 7% of the high price days will
result in a significant reduction in the average all-in power price from
approximately $31 per MWh to approximately $22 per MWh, or an approximate 30%
reduction. Moreover, the average all-in power price standard deviation, which is
a measure of price volatility, falls from approximately $50 per MWh to
approximately $10 per MWh, or an approximate 80% reduction. Based on this
analysis, it is apparent how EPM can offer contract power prices below the
forecasted annual average all-in market power prices; namely by effectively
selecting out those price periods in which to dedicate its sales to the PJM
market.
EXHIBIT 6: AVERAGE ALL HOUR ALL-IN POWER PRICE AND ITS STANDARD DEVIATION
AS A FUNCTION OF THE TOTAL AVAILABLE DAYS PER YEAR IN THE PJM MARKET
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[CHART]
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OPTION VALUE ANALYSIS
The option value analysis quantifies the value to EPM of the energy delivery
flexibility embedded within the PSA by quantifying market priced option premiums
via the implied market volatility for power options traded in the PJM region.
The time-of-delivery flexibility provided in the PSA creates option value for
EPM, which essentially lowers its all-in cost of energy relative to average
market prices in two ways. First, the potential for downward price movements in
the market allows EPM to extract volatility value by selectively selling
(putting) energy to Cedar Brakes under the PSA at prices below forecasted market
levels. This "price-drop" value has been calculated by quantifying the monthly
put option premium in the PJM market. Second, as stated earlier, the potential
for price spikes in the summer peak periods allows EPM to extract value by
exercising its option to suspend energy deliveries to Cedar Brakes for five days
per month or approximately 23% of the time during the on-peak summer period.
This value is quantified by summing the value of the premiums earned on the sale
of one-day power call options that could be sold during approximately five days
of each summer month. These options effectively allow EPM to extract a portion
of the highest energy prices of the year for its own account (i.e., quantifying
the value of not supplying power to Cedar Brakes when the market is
hyper-inflated) and thus lower the average monthly all-in energy cost to EPM of
selling energy to Cedar Brakes under the PSA.
EXHIBIT 7: RELATIONSHIP OF EPM CONTRACT PRICE TO MARKET PRICE
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Exhibit 7 illustrates the general relationship of market price to EPM's contract
price under the PSA using the option value adjustment methodology. The contract
price is equal to the average annual market price reduced by the value for the
sale of on-peak call and put options and off-peak put options. Deriving market
implied volatility for the PJM market and utilizing options pricing models, we
calculated the value of the on-peak and off-peak put options and the on-peak
call options for the term of the contract (i.e., 2000 through 2013). We
subtracted option premia from our power price forecast for the PJM market to
arrive at adjusted market power prices or comparative contract prices. The
results are presented below in Exhibit 8.
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EXHIBIT 8: SUMMARY OF THE AVERAGE ALL HOUR "ALL-IN" POWER PRICES ($/MWh)
FOR THE EPM CONTACT AND FORECASTED OPTION VALUE ADJUSTED VALUES
- --------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------------------------------------
EPM PACE'S FORWARD PRICE OPTION VALUE
CONTRACT PRICE CURVE FORECAST ADJUSTED PRICE FORECAST
YEAR ($/MWH) ($/MWH) ($/MWH)
- -------------------------------------------------------------------------------------------------------------------
2000 $23.03 23.37 20.63
2001 $29.71 35.42 30.25
2002 $29.30 33.84 29.19
2003 $28.56 32.57 27.87
2004 $27.94 33.94 28.47
2005 $28.07 34.21 28.63
2006 $28.26 34.93 29.37
2007 $28.26 36.37 30.48
2008 $28.80 37.03 31.21
2009 $29.08 38.39 32.23
2010 $29.36 39.61 33.26
2011 $29.64 40.90 34.30
2012 $29.94 42.29 35.26
2013 $33.75 50.99 41.83
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PJM MARKET PRICE FORECAST
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The following section details the market price forecasting methodology used
to perform the bid strategy assessment of the PSA. This forecast provides the
expected level and distribution (time of day and season) of PJM East power
prices, based on Pace's CEMAS model. This section includes Pace's Base Case
forecast of market clearing prices for the period 2000-2013, an assessment of
the capacity availability resources within the PJM region, a key assumptions
description and methodology underlying the development of the forecast.
MARKET CLEARING PRICE FORECAST APPROACH
Pace's market clearing price forecast methodology consists of multiple,
interrelated analytical processes. Pace employed utility grade computer
simulation models to evaluate the existing supply and demand relationships in
the region, match future utility operations to forecasts of demand, and predict
the electricity prices resulting from industry deregulation.
APPROACH
Pace conducted a detailed analysis of the PJM market clearing prices. This
analysis provides in-depth insight into the fundamentals of the PJM and the
emerging competitive market within the region. The analysis is based on Pace's
competitive market vision of a "one-price" market for capacity and energy. A
description of Pace's approach to this analysis is described below.
Pace's approach incorporates five market analysis tools that provide the
capability to forecast market clearing prices for both capacity and energy. As
illustrated in Exhibit 9, CEMAS consists of five modules. These modules are:
1. REVENUE REQUIREMENT MODULE: This module compares fixed and variable
costs for all generating units with all-in revenues generated from a
given bidding strategy. It then reports information regarding over or
under-recovery (stranded costs) to the Bid Analysis Module.
2. UNIT FUEL PRICING MODULE: This module calculates fuel prices for each
unit and transfers the data to the Revenue Requirement Module. These
fuel pricing calculations take into account escalation schedules,
transportation costs, fuel quality, and fuel procurement and contractual
constraints.
3. BIDDING ANALYSIS MODULE: Based on the fixed and variable costs of
generating units and over and under-recovery data generated by the
Revenue Requirement Module, this module generates bids for each unit on
the system and transfers those bids to the Market Clearing Price Module
for production simulation.
4. HOURLY LOAD MODULE: The Hourly Load Module aggregates actual utility
hourly loads as reported to the Federal Energy Regulatory Commission
("FERC") to create an integrated system hourly load profile. This module
uses forecasts of peak and energy demand to develop the base system load
profile over the study period. The results of the Hourly Load Module are
drawn upon by the Market Clearing Price Module to simulate daily system
demand.
5. MARKET CLEARING PRICE MODULE: This module performs a detailed
operations and dispatch simulation based on bid prices generated by the
Bidding Analysis Module and the hourly load data generated by the Hourly
Load Module. For each hour in the study period, the module dispatches
generating units according to their bid prices and availabilities. The
Market Clearing Price Module uses a utility grade
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dispatch model to model the hourly system constraints of a regional
power pool, optimizing least cost generation choices to match demand
fluctuations. The module then produces hourly market clearing prices,
which are passed to the Revenue Requirement Module to evaluate system
operations and market price stability. Based on this analysis, CEMAS
will either produce a new iteration of optimized bids or, if the market
is deemed stable, summarize market-clearing prices for each study
period.
EXHIBIT 9: PAGE CEMAS METHODOLOGY
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[CHART]
- --------------------------------------------------------------------------------
CEMAS was designed based on Pace's market experience, which shows that clearing
prices of competitive generation markets are a function of the underlying
generation cost structure, supply availability and demand fluctuations, the
bidding strategies that participants adopt and the incremental cost of expansion
units. Pace has sought with CEMAS to integrate these components into a system
capable of accurately projecting market-clearing prices in a competitive market.
SIMULATED MARKET PRICE FORECAST FOR PJM
CEMAS SIMULATED MARKET PRICES
Pace's Base Case market price forecast was founded on our expected assumptions
underlying a competitive market. Specifically, given the cost structure of
generating units, demand, fuel pricing, and other key factors, the CEMAS model
simulated the PJM system and optimized unit dispatch and bidding to identify the
market pricing and price distribution to allow the system to recover all fixed
and variable costs of generation units except those fixed costs that are
determined above market or "stranded". Additionally, as discussed previously,
bidding strategies are set to achieve a market price within +/- 5% of the levels
which expansion capacity would require to cover their minimum fixed and variable
costs.
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AVERAGE SYSTEM ANNUAL TIME OF DAY PRICES
Exhibit 10 shows Pace's forecast of time of day prices for the study period 2000
through 2013. The time of day designation consists of peak, off-peak, and
weekend. The peak period consists of 16 hour blocks during the 5 day work-week,
while the off-peak period represents the remaining 8 hours during these 5 days.
The weekend designation represents 24-hour blocks for Saturday and Sunday.
Pace's Base Case market price forecasts for the PJM Northeast sub-region are
between $33.99/MWh and $28.67/MWh (measured in 1998 real dollars) for the period
from 2000 to 2013. Pace expects that electricity prices will remain stable over
the period as sufficient capacity is constructed to meet demand and efficiency
improvements offset a modest natural gas real price increase.
EXHIBIT 10: PJM NORTHEAST ANNUAL SYSTEM TIME OF DAY PRICES -- BASE CASE
(1998 $/MWh)
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- -------------------------------------------------
YEAR PEAK OFF-PEAK WEEKEND AVERAGE
- -------------------------------------------------
2000 51.08 16.08 20.41 33.99
2001 48.71 16.30 20.35 32.89
2002 44.83 15.72 19.51 30.66
2003 41.78 15.42 18.26 28.79
2004 42.45 15.56 18.73 29.27
2005 41.43 15.74 18.56 28.78
2006 41.21 16.01 18.34 28.67
2007 41.66 16.22 18.97 29.12
2008 41.34 16.27 18.81 28.93
2009 41.46 16.52 19.53 29.26
2010 41.60 17.06 19.51 29.45
2011 41.51 17.32 20.23 29.67
2012 42.04 17.54 20.07 29.93
2013 41.86 17.71 20.42 29.98
- -------------------------------------------------
- --------------------------------------------------------------------------------
ADJUSTED AVERAGE SYSTEM ANNUAL TIME OF DAY PRICES
Pace's annual time of day prices are used in the bid strategy analysis to assess
the potential for EPM to reasonably extract the higher price hours for its own
use (sales) in the PJM market, based on Pace's forward price curve forecast.
As shown in Exhibit 11, for the 2001 through 2006 period, Pace estimates the EPM
contract price to be in-line with Pace's adjusted market price forecast. For the
remainder of the forecast period, 2007-2013, Pace estimates the EPM contract
price to be slightly below Pace's adjusted market price. However, given the
increasing level of uncertainty as the time horizon grows more distant, we do
not believe that the contract price is significantly different from market
expectations. As such, on a net present value ("NPV") basis, the value ascribed
to the differential between the Pace-adjusted market prices and the EPM contract
prices is approximately 4%, assuming a discount rate of 10% and a 13-year term
of the contract.
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EXHIBIT 11: PJM AVERAGE ANNUAL EPM CONTACT AND BID STRATEGY PRICES (1998
$/MWh)
- --------------------------------------------------------------------------------
- ---------------------------------------------------------
BID STRATEGY
YEAR CONTRACT ANALYSIS PRICES
- ---------------------------------------------------------
2000* 23.03 22.09
2001 29.71 27.56
2002 29.30 26.40
2003 28.56 25.32
2004 27.94 26.46
2005 28.07 26.68
2006 28.26 27.26
2007 28.26 28.38
2008 28.80 28.94
2009 29.08 30.10
2010 29.36 31.06
2011 29.64 32.12
2012 29.94 33.25
2013* 33.75 34.21
- ---------------------------------------------------------
- --------------------------------------------------------------------------------
* The market prices for the years 2000 and 2013 represent partial years, as the
contract term begins September 2000 and expires August 2013.
WHOLESALE MARKET TRANSACTIONS
The PJM power market is a highly competitive and maturing wholesale market. The
market's competitiveness is evidenced by the region's large volume of power
transactions. Wholesale market trading in the area offers additional
opportunities to EPM to fulfill its on peak and off peak obligations and
capitalize on the flexibility of the PSA. The PJM power market has experienced
high wholesale market volumes of over 163,682 GWh in 1998 and more than 121,946
GWh through 3rd quarter 1999. Accordingly, the PPA/PSA volumes represent only
0.001% of the entire PJM market. Due to these high trading volumes within the
PJM market, the region is typically considered a liquid market. Additionally,
since the PPA/PSA is such a small percentage of the market, Pace concludes that
EPM will be able to fulfill its contract obligations without impacting the
larger market.
The high volume of area electricity interchange and the region's proximity to
liquid trading hubs such as the Cinergy trading hub, indicate a strong market
for sales to PJM's neighboring regions. PJM is bordered by the NERC sub-regions
of NYPP, VACAR, and ECAR. Within these areas, power market trading occurs within
three additional spot markets: ComEd, TVA, and Southern. ECAROT, on the northern
border of PJM, is host to Cinergy, the most active power trading market to date.
The high volume of area electricity interchange and the liquidity of these
markets indicate a strong market for sales/purchases for EPM. Exhibit 12 shows
quantities of electricity trades in all NERC regions.
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EXHIBIT 12: POWER MARKETER TRANSACTIONS BY NERC REGION(2)
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[CHART]
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EXISTING DEMAND PROFILE
For each utility's respective demand forecast, Pace reviewed published data from
the Regional Electricity Supply & Demand Projections (EIA-411) report submitted
by the NERC sub-regions to the U.S. Energy Information Administration (EIA). The
EIA-411 report provides historical and projected peak and energy demands shown
in Exhibit 13 for the combined sub-regions of Entergy-North, Entergy-Gulf, TVA,
and Southern.
Exhibit 13 indicates that PJM utilities expect summer peak demand and energy to
increase at an average rate of 1.71% and 1.68% per year over the next 10 years,
respectively. Specifically, peak demand is projected to grow from 48,445 MW to
50,576 MW between 1998 and 2000. Thereafter, peak demand is expected to rise to
approximately 57,381 MW by the year 2008. Net energy is expected to escalate
from a base of approximately 248,806 GWh in 1998 to nearly 293,958 GWh by the
year 2008.
- ---------------
2 Reflects power marketer transactions occurring during 1998. Transaction
volumes represent both interstate and intrastate trades.
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EXHIBIT 13: PJM DEMAND AND ENERGY REQUIREMENTS FORECAST
- --------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------------------------------------------------
*1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
- -------------------------------------------------------------------------------------------------------------------------------
Peak Demand Summer (MW) 48,445 49,807 50,576 51,426 52,238 53,048 53,892 54,769 55,634 56,516
Peak Demand Winter (MW) 36,532 43,009 43,628 44,264 44,917 45,575 46,247 46,947 47,631 48,321
Net Energy for Load (MWh) 248,806 254,967 258,859 263,326 267,951 271,635 276,230 280,506 284,900 289,339
System Load Factor 59.28% 61.85% 62.29% 61.71% 61.62% 61.51% 61.61% 62.04% 61.89% 61.63%
Summer Change (MW) 1,362 769 850 812 810 844 877 865 882
Winter Change (MW) 6,477 619 636 653 658 672 700 684 690
Energy Change (MWh) 6,161 3,892 4,467 4,625 3,684 4,595 4,276 4,394 4,439
Summer Change (%) 2.81% 1.54% 1.68% 1.58% 1.55% 1.59% 1.63% 1.58% 1.59%
Winter Change (%) 17.73% 1.44% 1.46% 1.48% 1.46% 1.47% 1.51% 1.46% 1.45%
Energy Change (%) 2.48% 1.53% 1.73% 1.76% 1.37% 1.69% 1.55% 1.57% 1.56%
Annual Summer Peak Growth 1.71%
Annual Winter Peak Growth 2.98%
Annual Energy Growth 1.68%
- ---------------------------- -----------
2008
- ---------------------------- -----------
Peak Demand Summer (MW) 57,381
Peak Demand Winter (MW) 48,981
Net Energy for Load (MWh) 293,958
System Load Factor 61.50%
Summer Change (MW) 865
Winter Change (MW) 660
Energy Change (MWh) 4,619
Summer Change (%) 1.53%
Winter Change (%) 1.37%
Energy Change (%) 1.60%
Annual Summer Peak Growth
Annual Winter Peak Growth
Annual Energy Growth
Source: EIA-411
*Actual
- --------------------------------------------------------------------------------
Also shown in Exhibit 13, the PJM market has a relatively high load factor of
over 59%. Over the forecast period, utilities are expecting this load factor to
increase to approximately 62%. This increasing load factor is attributable to
energy demand growing at a faster rate than the system peak. If the system load
factor does not improve, this will increase the amount of capacity needed to
meet reserve and reliability requirements. However, to be conservative, Pace's
market study assumes that the customer mix, load shape, and consequently this
high load factor will be achieved throughout the study period, thereby slightly
minimizing the need for incremental expansion capacity.
Despite the aforementioned load factor improvement, as is shown in Exhibit 14,
PJM utilities are expecting a declining summer reserve margin varying between
5%-14%. This declining reserve margin is due to expectations that only
approximately 2,396 MW of net capacity additions can be achieved in the next 10
years. Therefore, the demand increases will outpace the capacity improvements.
As is shown in Exhibit 14, it is expected that there will be 55,470 MW of
capacity present in the PJM power market during the summer of 2000. The contract
capacity specified in the PSA of approximately 123 MW represents approximately
0.2% of the total existing capacity in this market. The low market share coupled
with a well-developed electrical transmission system, capable of transferring
high quantities will allow EPM to access numerous power purchasers for excess
capacity and energy sales/purchases. Therefore, EPM will have many physical
options to fulfill its on-peak and off-peak obligations and utilize the
flexibility of the PSA.
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EXHIBIT 14: PJM MARKET DEMAND AND RESERVE MARGIN FORECAST -- SUMMER
- --------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------------------------------------
1999 2000 2001 2002 2003 2004 2005 2006 2007
- ----------------------------------------------------------------------------------------------------------------------------------
Internal Demand 49,807 50,576 51,426 52,238 53,048 53,892 54,769 55,634 56,516
Standby Demand 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Total Internal Demand 49,807 50,576 51,426 52,238 53,048 53,892 54,769 55,634 56,516
Direct Ctrl Load Mgt 800.00 800.00 799.00 799.00 800.00 800.00 800.00 801.00 800.00
Interruptible Demand 1,381 1,416 1,423 1,430 1,431 1,432 1,434 1,435 1,437
Net Internal Demand 47,626 48,360 49,204 50,009 50,817 51,660 52,535 53,398 54,279
Total Owned Capacity 52,037 52,061 52,385 52,955 53,211 53,327 53,715 54,419 54,735
Inoperable Capacity 0 0 0 0 0 0 0 0 0
Net Operable Capacity 52,037 52,061 52,385 52,955 53,211 53,327 53,715 54,419 54,735
IPPs 4,151.00 4,197.00 4,197.00 4,197.00 4,114.00 3,736.00 3,736.00 3,736.00 3,736.00
Capacity Purchases 649 518 518 518 518 518 518 518 68
Full Response Purchases 450 450 450 450 450 450 450 450 0
Capacity Sales 1,326 1,306 1,393 1,393 439 439 439 439 439
Full Response Sales 954 954 954 954 0 0 0 0 0
Planned Capacity Res 55,511 55,470 55,707 56,277 57,404 57,142 57,530 58,234 58,100
Reserve Margin (MW) 7,885 7,110 6,503 6,268 6,587 5,482 4,995 4,836 3,821
Reserve Margin (%) 14.20% 12.82% 11.67% 11.14% 11.47% 9.59% 8.68% 8.30% 6.58%
- -------------------------------- ------------
2008
- -------------------------------- ------------
Internal Demand 57,381
Standby Demand 0.00
Total Internal Demand 57,381
Direct Ctrl Load Mgt 802.00
Interruptible Demand 1,438
Net Internal Demand 55,141
Total Owned Capacity 54,558
Inoperable Capacity 0
Net Operable Capacity 54,558
IPPs 3,720.00
Capacity Purchases 68
Full Response Purchases 0
Capacity Sales 439
Full Response Sales 0
Planned Capacity Res 57,907
Reserve Margin (MW) 2,766
Reserve Margin (%) 4.78%
Source: EIA-411
- --------------------------------------------------------------------------------
EXHIBIT 15: PJM MARKET DEMAND AND RESERVE MARGIN FORECAST -- WINTER
- --------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------------------------------------
1999 2000 2001 2002 2003 2004 2005 2006 2007
- ----------------------------------------------------------------------------------------------------------------------------------
Internal Demand 43,009 43,628 44,264 44,917 45,575 46,247 46,947 47,631 48,321
Standby Demand 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Total Internal Demand 43,009 43,628 44,264 44,917 45,575 46,247 46,947 47,631 48,321
Direct Ctrl Load Mgt 121.00 122.00 123.00 123.00 124.00 126.00 126.00 127.00 128.00
Interruptible Demand 1,029 1,029 1,029 1,029 1,029 1,029 1,029 1,029 1,029
Net Internal Demand 41,859 42,477 43,112 43,765 44,422 45,092 45,792 46,475 47,164
Total Owned Capacity 54,360 54,384 54,708 55,278 55,534 55,650 56,038 56,742 57,058
Inoperable Capacity 0 0 0 0 0 0 0 0 0
Net Operable Capacity 54,360 54,384 54,708 55,278 55,534 55,650 56,038 56,742 57,058
IPPs 4,279.00 4,325.00 4,325.00 4,325.00 4,242.00 3,870.00 3,870.00 3,870.00 3,870.00
Capacity Purchases 623 518 518 518 518 518 518 68 68
Full Response Purchases 450 450 450 450 450 450 450 0 0
Capacity Sales 1,306 1,306 1,393 1,393 439 439 439 439 439
Full Response Sales 954 954 954 954 0 0 0 0 0
Planned Capacity Res 57,956 57,921 58,158 58,728 59,855 59,599 59,987 60,241 60,557
Reserve Margin (MW) 16,097 15,444 15,046 14,963 15,433 14,507 14,195 13,766 13,393
Reserve Margin (%) 27.77% 26.66% 25.87% 25.48% 25.78% 24.34% 23.66% 22.85% 22.12%
- -------------------------------- ------------
2008
- -------------------------------- ------------
Internal Demand 48,981
Standby Demand 0.00
Total Internal Demand 48,981
Direct Ctrl Load Mgt 129.00
Interruptible Demand 1,029
Net Internal Demand 47,823
Total Owned Capacity 56,881
Inoperable Capacity 0
Net Operable Capacity 56,881
IPPs 3,854.00
Capacity Purchases 0
Full Response Purchases 0
Capacity Sales 0
Full Response Sales 0
Planned Capacity Res 60,735
Reserve Margin (MW) 12,912
Reserve Margin (%) 21.26%
Source: EIA-411
- --------------------------------------------------------------------------------
BASE CASE ASSUMPTIONS
The following presents Pace's major input assumptions used in the integrated
market pricing forecast of PJM. The input assumptions for the forecast are
presented in the following six categories:
- Regional Market Definition and Transmission Interchange
- Demand Forecast
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- Fuel Price Forecast
- Existing Generating Capacity Profiles
- Expansion Generating Capacity Profiles
REGIONAL MARKET DEFINITION AND TRANSMISSION INTERCHANGE
Based on the review of existing transmission transfer capabilities and recent
transmission assessment studies, Pace developed the major intra-regional market
areas of PJM as South, Southeast, Northeast, Central, and ACE. Exhibit 16
illustrates the PJM sub-regional designations to be employed in Pace's
simulation.
EXHIBIT 16: PJM SUB-REGIONAL DESIGNATIONS
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Major PJM utility service territories were allocated to sub-regions as follows:
- PJM SOUTH -- Baltimore Gas & Electric, Potomac Electric Power Co
- PJM SOUTHEAST -- Delmarva Power & Light Co
- PJM CENTRAL -- Pennsylvania Power & Light Co, Pennsylvania Electric Co.,
Metropolitan Edison Co.
- PJM NORTHEAST -- PECO Energy Co, Jersey Central Power & Light Co, Public
Service Electric & Gas Co.
- PJM ACE -- Atlantic City Electric Company
Generally, power in PJM flows from West to East, from low cost, low demand areas
in the West to high cost, high demand areas in the East. Such power transfers
tax the system heavily, creating less flexibility for system
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balance and emergency response. To slow the region's increasing transmission
congestion, the PJM Interconnection has designed location-based market pricing
systems ("LBMP") to provide market-based incentives to site capacity resources
near load centers and thereby relieve system constraints. Pace's subdivisions
were created to reflect such locational pricing based on regional transmission
zones and inter-regional constraints. Exhibit 17 provides the intra-regional
transfer capability schematic for PJM employed in the simulation.
EXHIBIT 17: ASSUMED PJM MARKET AREA TRANSMISSION CONSTRAINTS
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Pace simulates all resources in PJM including each transmission area's native
load and capacity. Additionally, inter-regional transfers with utilities that
are more than one wheel away from PJM are modeled on a net transaction basis
(i.e., net purchases or sales are simulated, but full resource optimization is
not conducted). Net transactions were developed utilizing historical wholesale
transactions as reported to the FERC for the years 1995 to 1998 and are outlined
in Exhibit 18. These transactions are modeled as available energy to the region
designated at the running system marginal cost.
EXHIBIT 18: HISTORIC INTER-REGIONAL TRANSACTIONS
- --------------------------------------------------------------------------------
FROM TO MW
NYPP PJM 200
MAIN PJM 350
SERC PJM 300
ECAR PJM 800
- --------------------------------------------------------------------------------
REGIONAL DEMAND FORECAST
Pace developed an independent demand forecast for each of the five sub-regions
in PJM. The following summarizes Pace's demand forecast methodology and results.
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PACE'S INDEPENDENT LOAD FORECASTING METHODOLOGY
Pace's independent demand forecast was developed according to the methodology
illustrated in Exhibit 19. This methodology has two primary components. The
first is the use of econometric models to forecast annual energy and peak demand
levels based on changes in population, employment, income, and other relevant
economic indicators. The second component of the methodology is the translation
of historical hourly demand levels and forecasted peak demand to create
predicted hourly load for each forecast year.
Typically, the most accurate means of projecting future demand is not done
solely by analyzing past trends in peak and energy demand, but by analyzing the
underlying factors that drive the consumption of electricity. This approach is
often referred to as a "bottom-up" analytical approach. As shown in Exhibit 19,
the foundation of Pace's load forecasting methodology is a bottom-up analytical
approach.
EXHIBIT 19: PACE LOAD FORECASTING METHODOLOGY
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Pace generated its demand forecast based on the historical relationships between
regional demand and multiple historic economic indicators (examples: population,
employment and income) between 1990-1999. To generate this demand forecast,
Pace:
- Established the historical relationship between net energy for load,
population, employment, and disposable income in PJM.
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- Forecast a Base demand case based on the historical trends in population,
employment, and personal income.
- Forecast a Low demand case based on a forecast of these same economic
indicators projected forward at a slowed economic growth rate equal to
3/4 the rate of historic trends.
- Forecast a High demand case based on a nominal increase in population
growth relative to the historical trend.
- Calculated seasonal energy and summer/winter peaks according to
historical usage patterns and load factors.
Other issues considered with respect to Pace's independent forecast include:
- Normal weather conditions are assumed with no factors included to
simulate extreme weather conditions.
- The forecast incorporated all demand and energy reductions from utility
dispatchable and non-dispatchable DSM programs as published in utility
demand forecasts. Pace believes that this is a conservative assumption in
that many DSM programs are aggressive in future years and will likely
fall short of their stated goals.
For purposes of the Base Case, Pace will simulate our base case demand forecast,
which is consistent with future expectations. The low and high demand cases are
developed for comparison and, ultimately, for sensitivity analyses.
ENERGY DEMAND FORECAST RESULTS
Pace's analysis indicates that PJM's historical growth in retail electricity
sales correlated to changes in employment, personal income, and population with
a high degree of reliability. Pace's regression analysis resulted in a
correlation coefficient of 94%. The resulting forecast of PJM system load is
illustrated in Exhibit 20 and provided in tabular form in Exhibit 21. The
summary of the energy forecast results are outlined below:
- Pace expects that regional electricity demand growth will slow from
historic long-term trends. Historically, demand has grown at an average
rate of 1.80% per year in PJM. Pace forecasts annual demand growth
through 2013 for PJM at 1.64%.
- In the near-term (2000-2008), Pace forecasts a slightly higher energy
growth rate for PJM than the currently filed utility forecasts.
Specifically, Pace expects a 1.63% average annual growth rate over the
period versus the PJM utility forecast of 1.60%.
- In contrast to PJM's historical annual load growth rate of 1.80%, the
pool forecasts future growth rates to average 1.60% annually over the
next 10 years.
- --------------------------------------------------------------------------------
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EXHIBIT 20: PACE PJM ENERGY FORECAST -- GWh
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
EXHIBIT 21: PACE PJM ENERGY FORECAST -- GWh
- --------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------
PJM PACE PJM PACE PJM
UTILITIES' PACE PJM ENERGY ENERGY PACE PJM
ENERGY ENERGY FORECAST FORECAST ENERGY
DEMAND BACKCAST LOW CASE BASE CASE FORECAST HIGH
(GWH) (GWH) (GWH) (GWH) CASE (GWH)
- ------------------------------------------------------------------------------------
HISTORIC
- ------------------------------------------------------------------------------------
1990 221,099 220,691
1991 228,588 225,649
1992 226,154 230,377
1993 235,980 235,134
1994 238,379 238,557
1995 243,043 241,451
1996 243,328 243,977
1997 243,967 246,684
1998 248,806 251,095
1999 259,644 255,209
- ------------------------------------------------------------------------------------
FORECAST
- ------------------------------------------------------------------------------------
2000 258,859 257,284 259,371 260,728
2001 263,326 259,377 263,602 266,370
2002 267,951 261,488 267,904 272,135
2003 271,635 263,616 272,278 278,026
2004 276,230 265,761 276,726 284,048
2005 280,506 267,925 281,247 290,202
2006 284,900 270,107 285,844 296,492
2007 289,339 272,306 290,519 302,920
2008 293,958 274,525 295,271 309,490
2009 276,761 300,104 316,205
2010 279,017 305,017 323,068
2011 281,291 310,013 330,083
2012 283,584 315,093 337,252
2013 285,896 320,258 344,580
- ------------------------------------------------------------------------------------
Gr. Rate 1990-1999 1.80% 1.63%
- ------------------------------------------------------------------------------------
Gr. Rate 2000-2008 1.60% 0.81% 1.63% 2.17%
- ------------------------------------------------------------------------------------
Gr. Rate 2000-2013 0.81% 1.64% 2.17%
- ------------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
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The PJM energy forecast reflects an aggregation of Pace's development of a
sub-regional forecast for ACE, Central, Northeast, South and Southeast. As shown
in Exhibit 22, energy demand in the Southeast is expected to grow at the highest
annual average rate of 2.47% from 17,532 GWh in 1999 to 24,866 GWh in 2013.
Energy demand growth in the Southeast is followed by ACE at 2.01%, South at
1.60%, Northeast at 1.57%, and Central at 1.47%.
EXHIBIT 22: PACE SUB-REGIONAL ENERGY FORECAST FOR PJM -- GWh
- --------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------
PACE'S ENERGY FORECAST(GWH) UTILITIES'
ENERGY
FORECAST
- -----------------------------------------------------------------------------------------------
ACE CENTRAL NORTHEAST SOUTH SOUTHEAST TOTAL
- -----------------------------------------------------------------------------------------------
HISTORIC
- -----------------------------------------------------------------------------------------------
1990 8,686 58,124 88,500 51,674 14,115 221,099
1991 9,030 60,057 91,424 53,344 14,734 228,588
1992 8,982 59,382 90,379 52,697 14,715 226,154
1993 9,424 61,924 94,230 54,904 15,498 235,980
1994 9,572 62,516 95,112 55,379 15,800 238,379
1995 9,812 63,701 96,895 56,377 16,257 243,043
1996 9,878 63,738 96,931 56,359 16,423 243,328
1997 9,958 63,867 97,108 56,422 16,612 243,967
1998 10,155 64,534 99,034 57,541 17,541 248,806
1999 10,459 67,027 104,063 60,563 17,532 259,644
- -----------------------------------------------------------------------------------------------
FORECAST
- -----------------------------------------------------------------------------------------------
2000 10,598 67,169 103,225 60,282 18,096 259,371 258,859
2001 10,811 68,158 104,841 61,247 18,544 263,602 263,326
2002 11,029 69,162 106,483 62,228 19,003 267,904 267,951
2003 11,251 70,180 108,150 63,224 19,473 272,278 271,635
2004 11,477 71,214 109,843 64,236 19,955 276,726 276,230
2005 11,708 72,263 111,563 65,264 20,449 281,247 280,506
2006 11,943 73,327 113,310 66,309 20,955 285,844 284,900
2007 12,184 74,407 115,084 67,370 21,474 290,519 289,339
2008 12,429 75,502 116,886 68,449 22,005 295,271 293,958
2009 12,679 76,614 118,717 69,545 22,550 300,104
2010 12,934 77,742 120,575 70,658 23,108 305,017
2011 13,194 78,887 122,463 71,789 23,680 310,013
2012 13,459 80,049 124,381 72,938 24,266 315,093
2013 13,730 81,227 126,328 74,106 24,866 320,258
- -----------------------------------------------------------------------------------------------
Gr. Rate 1990-1999 2.08% 1.60% 1.82% 1.78% 2.44% 1.80%
- -----------------------------------------------------------------------------------------------
Gr. Rate 2000-2008 2.01% 1.47% 1.57% 1.60% 2.47% 1.63% 1.60%
- -----------------------------------------------------------------------------------------------
Gr. Rate 2000-2020 2.01% 1.47% 1.57% 1.60% 2.47% 1.64%
- -----------------------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
Pace also developed the summer and winter peak demand for each sub-region based
on each subregional energy forecast reflecting historical load factors. Pace's
forecast for winter and summer peak demand for each PJM sub-region along with
utility filed peak forecasts are detailed in Exhibit 23.
- --------------------------------------------------------------------------------
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[PACE LOGO]
EXHIBIT 23: PACE SUB-REGIONAL PEAK DEMAND FORECAST FOR PJM -- MW
- --------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------------------------------
PACE NON-
ACE CENTRAL NORTHEAST SOUTH SOUTHEAST COINCIDENT PEAK
- -----------------------------------------------------------------------------------------------------------------------
SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER
- -----------------------------------------------------------------------------------------------------------------------
HISTORIC
------------------------------------------------------------------------------------------------------------------
1993
1994
1995
1996
1997
1998
1999
------------------------------------------------------------------------------------------------------------------
FORECAST
------------------------------------------------------------------------------------------------------------------
2000 2,326 1,663 12,106 11,519 20,923 16,345 12,295 10,741 3,658 3,275 51,309 43,543
2001 2,361 1,688 12,240 11,646 21,168 16,536 12,443 10,870 3,726 3,336 51,938 44,076
2002 2,397 1,713 12,376 11,775 21,416 16,730 12,592 11,000 3,796 3,397 52,576 44,617
2003 2,433 1,739 12,513 11,906 21,667 16,927 12,743 11,133 3,866 3,461 53,222 45,165
2004 2,470 1,765 12,651 12,038 21,922 17,125 12,896 11,266 3,938 3,525 53,877 45,720
2005 2,507 1,792 12,792 12,171 22,179 17,326 13,051 11,402 4,011 3,591 54,540 46,282
2006 2,544 1,819 12,934 12,306 22,439 17,530 13,208 11,539 4,086 3,658 55,212 46,852
2007 2,583 1,846 13,077 12,443 22,703 17,735 13,367 11,678 4,162 3,726 55,893 47,429
2008 2,622 1,874 13,223 12,581 22,969 17,944 13,529 11,819 4,240 3,795 56,582 48,013
2009 2,661 1,902 13,370 12,722 23,239 18,154 13,692 11,961 4,319 3,866 57,281 48,606
2010 2,701 1,931 13,519 12,863 23,512 18,368 13,857 12,105 4,400 3,939 57,989 49,206
2011 2,742 1,960 13,670 13,007 23,788 18,584 14,024 12,251 4,483 4,013 58,707 49,814
2012 2,783 1,989 13,822 13,152 24,068 18,802 14,193 12,399 4,567 4,088 59,433 50,431
2013 2,825 2,019 13,977 13,299 24,351 19,023 14,365 12,549 4,652 4,165 60,170 51,055
- ---------------------------------------------------------------------------------------------------------------------
- ---------- -----------------
PJM UTILITIES
COINCIDENT PEAK
- ---------- -----------------
SUMMER WINTER
- ---------- -----------------
HISTORIC
------------------------------------------------------------------
1993 46,494 41,406
1994 46,019 40,653
1995 48,577 40,790
1996 44,302 40,468
1997 49,464 37,217
1998 48,445 36,532
1999 51,600 38,123
---------------------------------------------------------------------------------------------
FORECAST
------------------------------------------------------------------------------------------------------------------------
2000 50,576 43,628
2001 51,426 44,264
2002 52,238 44,917
2003 53,048 45,575
2004 53,892 46,247
2005 54,769 46,947
2006 55,634 47,631
2007 56,516 48,321
2008 57,381 48,981
2009
2010
2011
2012
2013
- ---------------------------------------------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
Pace used an hourly load module tool to translate annual peak and energy demand
growth factors into future hourly demand for the study period. The translation
process is a two step process:
1) The first step involves aggregating actual utility hourly loads as
reported to the FERC (for each utility under consideration in this study). This
aggregation creates integrated hourly system load profiles, or base system
hourly load files, for each transmission area in the PJM market.
2) The second step involves applying annual growth factors and seasonal
peak demand forecasts to the base system hourly load file, to create hourly
demand files for each year in the study.
Pace assumed that the basic historic system load shape as represented by 1998
values would be maintained throughout the study. However, system load factors do
change slightly as the result of applying annual peak and energy growth factors.
As the relationship of peak demand and energy change, the system load factor and
shape will shift.
FUEL PRICING
Pace developed fuel price forecasts for each major fuel (natural gas, No. 2
distillate fuel oil, No. 6 residual fuel oil, coal, and uranium) in the PJM
market region. The base year fuel prices and annual escalation rates in the
forecast are based on Pace's analysis of historical price data and the
fundamental factors driving each fuel market. All forecast prices are in 1998
real dollars and represent a regional benchmark market price.(3)
Pace's forecasting methodology recognizes that actual prices to existing
facilities often vary from the regional benchmark due to
advantages/disadvantages in supply contract terms or transportation rates. To
develop plant-specific fuel forecasts for these facilities, the regional
benchmark price is adjusted to reflect plant-specific cost factors. These
plant-specific cost factors are maintained throughout the forecast.
- ---------------
3 Gas-fired expansion plants are assigned the natural gas regional benchmark
price.
- --------------------------------------------------------------------------------
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[PACE LOGO]
Pace applies monthly fuel adjustment factors as shown in Exhibit 24 to reflect
monthly fluctuations in fuel prices.
EXHIBIT 24: MONTHLY FUEL PRICE ADJUSTMENT FACTORS
- --------------------------------------------------------------------------------
- ----------------------------------------------------------
MONTH GAS COAL NO. 2 NO. 6 JET
- ----------------------------------------------------------
Jan 126% 102% 102% 108% 106%
Feb 122% 101% 103% 103% 103%
Mar 110% 99% 99% 97% 97%
Apr 94% 95% 102% 99% 101%
May 85% 101% 100% 98% 97%
Jun 85% 102% 95% 97% 95%
Jul 85% 102% 94% 98% 95%
Aug 85% 102% 96% 94% 98%
Sep 86% 102% 102% 96% 101%
Oct 94% 94% 104% 102% 104%
Nov 109% 100% 102% 103% 103%
Dec 119% 98% 101% 106% 102%
- ----------------------------------------------------------
- --------------------------------------------------------------------------------
The remainder of this section reviews Pace's major conclusions and base case
assumptions regarding fuel pricing.
NATURAL GAS
Pace's independent forecast of delivered natural gas prices in PJM is comprised
of commodity prices, represented by the price for gas on the New York Mercantile
Exchange ("NYMEX") at the Henry Hub in Louisiana, plus a regional basis
adjustment to reflect price differentials between the Gulf Coast and various PJM
delivered price sub-regions.
Commodity Prices
In general, Pace expects Henry Hub commodity prices to decline from expected
year 2000 price levels through 2003. Thereafter, Pace expects a 0.5% annual real
price increase throughout the forecast period. Fundamental factors driving
Pace's Henry Hub commodity forecast are:
- Short-term production reductions over mid-1998 to mid-1999 were in
response to low prices and high inventory levels, which resulted from low
domestic demand brought about by warmer than normal weather over the past
two years. This decrease in supply, and expectations for more normal
weather and gas demand this winter, caused prices to increase in the
later half of 1999 and in the NYMEX futures strip for 2000.
- Stronger than normal activity, from 2000 to 2002, will occur in the
expansion of the North American pipeline grid and production capacity,
particularly from the Western Canadian Sedimentary Basin and Sable
Island. The expansions will increase gas on gas competition in the
Midwest and Northeast U.S. and displace some Gulf Coast supply, causing
Henry Hub prices to decline from current levels.
- Gulf Coast production levels will remain flat as declines are offset by
increases in deep water offshore drilling.
- Canadian imports and associated infrastructure development will level off
after 2003.
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[PACE LOGO]
- Shifting preferences in energy consumption and power generation spurred
by environmental regulations for cleaner, more efficient natural gas will
support a slightly higher long-term real price escalation relative to
other fuels.
- A continued decline in finding and production costs, brought about by
technological advancements, will allow for lower inventories and a more
economically driven and responsive E&P sector. These fundamentals will
keep real price escalation from rising too high relative to other fuels.
Exhibit 25 provides an annual summary of Pace's independent forecast of the
Henry Hub and the delivered prices to each respective PJM fuel sub-region.
EXHIBIT 25: PJM NATURAL GAS PRICE FORECASTS (1998 $/MMBtu)
- --------------------------------------------------------------------------------
------------------------------------------------------
HENRY PJM NORTHERN
YEAR HUB PJM EAST DELMARVA WEST NJ
------------------------------------------------------
2000 2.88 3.37 3.35 3.60 3.27
2001 2.75 3.22 3.20 3.45 3.12
2002 2.47 2.98 2.94 3.19 2.86
2003 2.33 2.86 2.82 3.07 2.74
2004.. 2.34 2.89 2.85 3.10 2.77
2005.. 2.35 2.92 2.88 3.13 2.80
2006.. 2.36 2.93 2.89 3.14 2.81
2007.. 2.37 2.94 2.90 3.15 2.82
2008.. 2.39 2.96 2.92 3.17 2.84
2009.. 2.40 2.97 2.93 3.18 2.85
2010.. 2.41 2.98 2.94 3.19 2.86
2011.. 2.42 2.99 2.95 3.20 2.87
2012.. 2.43 3.00 2.96 3.21 2.88
2013.. 2.45 3.02 2.98 3.23 2.90
------------------------------------------------------
- --------------------------------------------------------------------------------
Regional Basis
The delivered gas price forecast incorporates general price differentials and
the cost of transportation to the PJM gas price sub-regions as depicted in
Exhibit 26.
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[PACE LOGO]
EXHIBIT 26: PACE GAS PRICE SUBREGIONS -- PJM
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Each gas price region is defined by its primary liquid supply source interstate
transporter and that transporter's applicable market-based transportation rates.
The regional basis from the Henry Hub to these gas price regions is driven
primarily by the following fundamentals:
- Transportation rates in PJM will experience some incremental competition
during the early part of the mid-term as projects, such as Millennium,
are built to bring excess Midwestern supply to markets in the Northeast.
- Eastern PJM receives supply primarily off of Texas Eastern Transmission
(TETCO) and Transcontinental Gas Pipeline (Transco). These pipelines
terminate in the New York City (NYC) market area, which sets the price
for deliveries in this area. Eastern PJM markets can receive supply just
upstream of constraint points heading into NYC and therefore are priced
at a $0.04/MMBtu discount to delivered prices in the NY City region. On
an annual average basis, prices in Western PJM are approximately
$0.10/MMBtu less than prices in Eastern PJM. This price discrepancy is
attributed to the region's proximity to Appalachian supply and access to
more available pipeline capacity on Columbia Transmission (TCO) and CNG
Transmission (CNG). Markets in Northern New Jersey receive supply
primarily from Transco and TETCO. These deliveries are downstream of
seasonal constraint points that cause delivered supply to average
approximately $0.04/MMBtu over PJM East deliveries on an annual average
basis. Markets located in the DelMarVa Peninsula do not have direct
access to interstate pipeline systems and, therefore, must use the local
distribution companies to obtain delivery of supply. Pace assumes a
transportation charge of $0.25/MMBtu in addition to PJM East delivered
prices.
- --------------------------------------------------------------------------------
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[PACE LOGO]
FUEL OIL
Pace forecasts prices for No. 2 distillate oil and No. 6 residual oil for PJM
based on the consumption profile of the generators in the region. The forecast
prices are comprised of the following components, which are detailed in the
remainder of this section:
- Commodity prices as represented by the price for West Texas Intermediate
("WTI") crude oil on the NYMEX in Cushing, Oklahoma,
- Location basis, and
- Crack spreads.
Commodity Prices
Following extremely depressed market conditions in 1997-98, when prices for some
crude grades slipped into single digits, there has been a significant rally in
crude oil prices since late 1999. Recent price strength is attributed to low
inventory levels brought about by effective compliance by OPEC members with
reduced output quotas and demand growth stemming from a continued strong US
economy and gradual economic recovery in Asia. Prices are currently at levels
that will stimulate non-OPEC production and encourage OPEC members to either
exceed current production quotas or revise the quotas to sanction higher output
levels. Therefore, it is Pace's view that average world prices (as measured by
the IRAC) will settle at levels that are comparable to the average real price
for the five-year period prior to the 1998 price collapse. Pace's WTI commodity
forecast is based on the following key fundamentals:
OPEC Production
- Compliance by OPEC members to production cuts will continue through the
first quarter of 2000. The continued reduction in supply will prop prices
up through mid 2000 when signs of increased production activity from
non-OPEC members and the potential elimination of cuts by OPEC members
should become visible causing prices to gravitate toward a more
sustainable long term equilibrium price of approximately $20.88.
- Continued expansion of Iraqi production to 2.8 MMBD is expected by the
end of year 2000, consistent with UN Security Council resolutions. Iraq
has signaled its intent to expand production aggressively when UN
sanctions are lifted.
- OPEC will undertake relatively ambitious capacity expansion programs in
order to accommodate the projected rise in worldwide petroleum demand.
Much of the expansion will occur in the Persian Gulf where the
reserves-to-production ratio already exceeds 80 years.
- OPEC will refrain from further attempts to boost prices by curtailing
output, targeting a price range near recent historical averages prior to
the 1997-98 glut.
- OPEC's relative market share will grow from its current level of
approximately 40%, but will not surpass the historic high of 53% reached
in 1973.
Non-OPEC Production
- Non-OPEC production has been surprisingly resilient in the low price
environment prior to mid-1999, largely due to innovations in exploration
and drilling technologies and investment-friendly government policies.
While prices in the range forecast by Pace are sufficient to sustain, and
in some regions
- --------------------------------------------------------------------------------
PROPRIETARY & CONFIDENTIAL
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[PACE LOGO]
expand, output by non-OPEC producers, the relative share of non-OPEC
output will fall due to expected strong growth in OPEC production.
- US crude oil output, which has been declining since 1985 due to a
combination of lower prices and rising production costs, will continue
falling at a rate of about 1% annually. The impact of sharply lower
Alaskan oil output, which has historically represented about 25% of total
US crude oil production, is tempered somewhat by technological
innovations that improve success rates and lower costs for deepwater
exploration and production in the Gulf of Mexico.((4))
- Optimism remains high concerning the long-term resource potential of the
Former Soviet Union (FSU) region, but production growth will be slow
until after 2005 due to delays in startup of many Caspian Basin projects
as well as a generally pessimistic outlook for investment in Russia.
- North Sea production, the largest supply component in the European Union,
is expected to grow for the next several years before peaking and
entering a decline phase.
Oil Demand
- Flat to modest projected petroleum demand growth in industrialized
countries is projected due to lower expected GDP growth and a gradual
shift away from oil for non-transportation uses such as power generation
and space heating.
- Dramatic increases in demand in developing countries are anticipated
largely due to higher assumed rates of GDP growth as well as the greater
tendency in developing countries to use oil for a wider variety of
applications. GDP growth is expected to be strongest in the developing
economies of Asia, particularly China.
- FSU and Eastern Europe are projected to have relatively rapid GDP growth,
but the impact on petroleum demand is modest because the transition to a
market system will lead to offsetting improvements in energy efficiency.
Exhibit 27 shows Pace's crude oil price forecast for WTI for the period of
2000-2020.
EXHIBIT 27: WTI CRUDE OIL PRICE FORECAST (1998 $/MMBtu)
- --------------------------------------------------------------------------------
- --------------------------------------
WTI PRICE
YEAR FORECAST
- --------------------------------------
2000 4.31
2001 4.19
2002 4.07
2003 3.95
2004 3.83
2005 3.71
2006-2013 3.60
- --------------------------------------
- --------------------------------------------------------------------------------
- ---------------
(4) Combined with the expected growth in US oil demand, the decline in US
production implies an increase in US oil imports.
- --------------------------------------------------------------------------------
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[PACE LOGO]
Location Basis
An adjustment for WTI crude oil prices must be made to reflect the price
differentials between Cushing, OK and the oil regions presented in Exhibit 28.
The location adjustment for each region is calculated by reviewing the
differential between prices for oil product in Oklahoma and each oil sub-region.
EXHIBIT 28: PACE OIL PRICE SUB-REGIONS FOR PJM
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
A local delivery charge is also applied to local rack pricing to reflect
transport charges to the plant sites. The final regional Location Basis are
presented in Exhibit 29.
EXHIBIT 29: PJM FUEL OIL LOCATION BASIS (1998 $/MMBtu)
- --------------------------------------------------------------------------------
- ----------------------------------------------------
CUSHING, OK TO: LOCATION BASIS
- ----------------------------------------------------
PJM East (0.03)
PJM South (0.03)
PJM West 0.14
New York City &
Vicinity (0.12)
- ----------------------------------------------------
- --------------------------------------------------------------------------------
Refined Product Crack Spreads
Ten years of historical US Gulf Coast spot prices were used to determine the
average crack spreads between crude oil and No. 2 distillate and No. 6 residual.
The average crack spreads shown in Exhibit 30 are forecasted to determine the
refined product prices in each region.
- --------------------------------------------------------------------------------
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[PACE LOGO]
EXHIBIT 30: CRUDE OIL TO REFINED PRODUCT CRACK SPREADS (1998 $/MMBtu)
- --------------------------------------------------------------------------------
- ----------------------------------------------------------------------------
YEAR LS NO. 2 OIL NO. 2 OIL NO. 6-0.3% OIL NO. 6-1% OIL
- ----------------------------------------------------------------------------
1998 0.69 0.59 0.07 (0.38)
1999 0.65 0.50 (0.12) (0.39)
2000 0.63 0.50 (0.13) (0.44)
2001 0.62 0.49 (0.15) (0.49)
2002 0.61 0.49 (0.16) (0.54)
2003 0.60 0.49 (0.18) (0.59)
2004 0.59 0.48 (0.19) (0.64)
2005 0.59 0.48 (0.19) (0.64)
2006-13 0.59 0.48 (0.19) (0.64)
- ----------------------------------------------------------------------------
- --------------------------------------------------------------------------------
Delivered Oil Price Forecasts
By summing each of the oil price components detailed above, Pace's forecast of
annual delivered oil prices are provided in Exhibit 31.
EXHIBIT 31: FUEL OIL PRICE FORECAST BY PJM SUB-REGION (1998 $/MMBtu)
- --------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------------------------
PJM WEST (W PA, W M) PJM SOUTH (E MD) PJM EAST (E PA, NJ) NEW YORK CITY & VICINITY
- ----------------------------------------------------------------------------------------------------------------------
LS NO.6 NO.6 LS NO.6 NO.6 LS NO.6 NO.6 LS NO.6 NO.6
YEAR NO.2 NO.2 .3% 1% NO.2 NO.2 .3% 1% NO.2 NO.2 .3% 1% NO.2 NO.2 .3% 1%
- ----------------------------------------------------------------------------------------------------------------------
2000 5.08 4.94 4.31 4.01 4.91 4.77 4.14 3.84 4.91 4.77 4.14 3.84 4.82 4.68 4.05 3.75
2001 4.95 4.82 4.18 3.84 4.78 4.65 4.01 3.67 4.78 4.65 4.01 3.67 4.69 4.56 3.92 3.58
2002 4.82 4.70 4.05 3.67 4.65 4.53 3.88 3.50 4.65 4.53 3.88 3.50 4.56 4.44 3.79 3.41
2003 4.69 4.58 3.91 3.50 4.52 4.41 3.74 3.33 4.52 4.41 3.74 3.33 4.43 4.32 3.65 3.24
2004 4.56 4.46 3.78 3.33 4.39 4.29 3.61 3.16 4.39 4.29 3.61 3.16 4.30 4.20 3.52 3.07
2005 4.44 4.34 3.66 3.21 4.27 4.17 3.49 3.04 4.27 4.17 3.49 3.04 4.18 4.08 3.40 2.95
2006 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2007 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2008 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2009 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2010 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2011 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2012 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
2013 4.32 4.22 3.54 3.10 4.15 4.05 3.37 2.93 4.15 4.05 3.37 2.93 4.06 3.96 3.28 2.84
- ----------------------------------------------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
COAL FORECAST
Pace's coal price forecast reflects the market outlook for various sulfur grades
of coal, trends in the cost of coal transportation, historical data on the
composition of coal deliveries by sulfur grade and supply basin, expectations
for the timing of "over-market" coal contract expiration, and anticipated
changes in consumption profiles required to satisfy Phase II SO(2) emission
limits. Pace employs the following process to generate plant specific coal price
forecasts:
1. National trends in coal supply and demand were surveyed to forecast
escalation rates for coal commodity prices as a function of sulfur
grade.
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2. The current coal commodity price is established for each plant based on
historical data and a specific coal consumption profile is developed for
each plant relating to sulfur grade and contracting status (i.e., spot
vs. long-term contract).
3. Each plant's purchasing profile was reviewed to determine the transition
from above-market contract deliveries to market-based purchases.
4. Information from the preceding steps was combined with estimated
transportation rates from relevant producing regions to each plant to
obtain plant-specific forecasts of delivered coal costs.
To reflect variations in coal quality, Pace divides coal consumption by power
generators in PJM into three categories. The categories are based on three
sulfur grade ranges as defined in Exhibit 32.
EXHIBIT 32: DEFINITION OF COAL QUALITY GRADES
- --------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------
LBS S LBS SO(2) APPROX.
PER MMBTU PER MMBTU % S
- ------------------------------------------------------------------------------------
Low Sulfur* <0.60 <1.20 < 0.72
Medium Sulfur 0.6-1.67 1.20-3.34 0.72-2.00
High Sulfur >1.67 >3.34 >2.00
- ------------------------------------------------------------------------------------
* Represents average emission rate utilities are required to meet by January 1,
2000 under CAAA, or compliance coal.
- --------------------------------------------------------------------------------
The following discussion profiles historic and expected trends in the market
fundamentals underlying the demand, supply, and cost of coal delivered to
utilities in the PJM market. Ultimately, this information along with historic
delivered prices serves to develop the plant level delivered coal cost Pace
employs in the simulation of the PJM market.
Trends in Coal Supply
Pace's long-term coal market outlook is based on a review of fundamental market
drivers affecting overall coal prices and the relative values of specific coal
grades.
- Coal demand is expected to increase only slightly in the aggregate, with
modest growth in domestic electric generation consumption partially
offset by declining exports.
- Coal consumption for power generation will increase slightly as a result
of higher utilization rates at existing plants, and there may also be
additions to coal-fired generating capacity in later years.
- Composition of demand will shift in favor of lower sulfur grades that
facilitate compliance with CAAA90 Phase II SO(2) emissions limits.
- Mine productivity will continue to be the key supply side price driver.
There is a long-term trend of increasing mine productivity that will
continue to exert downward pressure on coal prices in the U.S.
- Productivity growth is unlikely to continue at historical rates for the
following reasons:
- Many of the less efficient mines have already been shut down and the
first waves of industry consolidation have already passed.
- Mining companies have dramatically reduced their investment in new
capacity and are currently idling (reducing production) capacity at
existing mines in response to the soft coal market.
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- Historically, U.S. utilities have purchased coal under long-term coal
supply contracts. In the short to medium term, significant numbers of
such contracts that are priced above market will expire and/or be
renegotiated, which will tend to lower the fuel cost for plants in the
region. These contract expirations will continue to release substantial
amounts of coal to the spot market as has been the case over the last
five years. Pace expects that the vast majority of the contracts priced
over-market specific to PJM will have expired around 2001, earlier than
similar such contracts in other NERC regions.
- Intensified competition among coal producers and shippers will stimulate
innovation and tighten operating margins to further reduce both
extraction and transportation costs.
- Increased cross-fuel competition from cleaner and more efficient natural
gas will put downward pressure on coal prices because of a shift in the
power generation sector toward gas.
While these factors will tend to depress overall coal prices, albeit not at
historical rates, it is likely that there will be a divergence in the relative
rates of price decline across coal grades. Factors affecting the price of
specific sulfur grades include:
- Compliance with stricter air quality standards under Phase II of the CAAA
is expected to increase demand, and thereby mitigate expected price
declines, for lower sulfur coal grades. The impact on demand for
low-sulfur coal will be determined by the market value of emission
allowances, capital cost of scrubbers, and the amount of emission
allowances banked by an individual generator. However, most electric
generation facilities have found the use of low sulfur coal to be the
most cost-effective option for complying with CAAA mandates.
- Demand for higher sulfur coal is expected to decline faster than other
grades as utilities and IPPs move to comply with stricter sulfur emission
standards, particularly until 2005 when additional scrubbers are
scheduled to be installed.
- Real price declines for medium sulfur coal will be bounded by the
economics of burning lower sulfur coal without scrubbing compared with
purchasing higher sulfur coals in conjunction with scrubbing or utilizing
emission allowances.
Commodity Profile and Forecast
Coal consumption in PJM is dominated by medium sulfur coal from Pennsylvania and
West Virginia, with the remainder split between high sulfur coal from Northern
Appalachia and low sulfur coal from Central Appalachia. Exhibit 33 depicts the %
allocation of coal quality by sulfur grade used by utilities in PJM.
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EXHIBIT 33: COAL CONSUMPTION BY SULFUR GRADE -- PJM
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
Based on a review of historical prices of coal delivered to utilities in the
study area, Pace established individual plant base year (1998) delivered prices
ranging from $0.94/MMBtu to $1.97/MMBtu in PJM. The base year prices were
derived using current full year of price data available from FERC Form 423 (June
1998 to May 1999). The range in delivered price is due to differences in each
plant's consumption profile with respect to sulfur level, varying transportation
rates and possible price discounts for large volume consumers. The varying base
year prices are also affected by the amount of coal under contract versus spot
purchases.
The accuracy of the FERC data was verified by comparing it to independent
estimates of delivered costs developed from mine-mouth price data published in
Coal Week and estimated transportation costs to plants in the study region.
The escalation rate for each plant's market-based coal price is weighted by its
past and projected consumption profile. Pace's forecasted coal price escalators
for each sulfur grade are provided in Exhibit 34.
EXHIBIT 34: PROJECTED REAL COMMODITY ESCALATION RATES BY SULFUR LEVEL
- --------------------------------------------------------------------------------
- ---------------------------------------------------------------------
CUM. AVG.
1998-
1998-05 2005-13 2013
- ---------------------------------------------------------------------
Low Sulfur -1.4% -0.7% -1.03%
Medium Sulfur -2.2% -1.7% -1.93%
High Sulfur -3.6% -2.4% -2.96%
- ---------------------------------------------------------------------
- --------------------------------------------------------------------------------
Pace's forecast is consistent with recent trends in Central Appalachia, but
implies that real prices at times will decline at a rate slower than the recent
historical trends for both Northern Appalachia and the Northern/ Central
Appalachia weighted average. In addition to slower productivity growth,
consolidation, and a recovery in export sales, this trend change is also due to
the expiration of long-term, above market contracts, as discussed previously.
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Transportation Profile and Forecast
The transportation component of PJM delivered coal prices was determined using
data and projections from Hill & Associates, Inc.'s ("Hill") Coal Demand and
Price Projections: Volume 1 and 2, prepared for the Gas Research Institute
("GRI") and data obtained from the Fieldston Coal Transportation Manual. The
Hill data includes detail on transportation costs trends by sulfur grade for
deliveries into various sub-regions of the study area.
As with coal commodity prices, the key driver of future coal transport costs is
productivity. Productivity gains through consolidation and the application of
new technology in the rail transportation industry will keep transportation
costs low or declining. Use of aluminum rail cars, improved scheduling and fleet
management, utilization of electronic control mechanisms, and better locomotive
engineering are factors contributing to decreased cycle times, increased
carrying capacity, and enhanced rail productivity. Barge rates are expected to
continue to be more volatile than rail rates, but retirement of old vessels and
the construction of new terminals, as well as rehabilitation of old terminals,
will keep barge rates on a declining trend in real terms.
The transportation component, both base year and projected, was calculated using
a weighted average depending on the source region for each plant's coal. In
general, Pace applied the average transportation rates projected by Hill for the
relevant supply and consumption regions. In the case of plants with a
significant component of mine-mouth coal, the transportation rate was adjusted
to reflect those plants' relatively lower transportation costs. Average
transportation escalation rates applied by Pace are provided in Exhibit 35.
EXHIBIT 35: PROJECTED AVERAGE TRANSPORTATION ESCALATION RATES
- --------------------------------------------------------------------------------
- ---------------------------------------------------------------------
CUM. AVG.
1998-
1998-05 2005-13 2013
- ---------------------------------------------------------------------
Low/Medium Sulfur -1.6% -1.0% -1.28%
High Sulfur -1.7% -1.0% -1.33%
- ---------------------------------------------------------------------
- --------------------------------------------------------------------------------
Plant Delivered Coal Costs
Pace developed delivered coal price forecasts for each coal-fired plant in the
study area utilizing each plant's coal consumption profile, base year price,
Pace's coal price escalators and the Hill transportation rate forecasts. The
resulting delivered coal price forecast on a regional level for each sulfur
grade is depicted in Exhibit 36.(5)
- ---------------
5 The regional level delivered coal price forecast was derived applying the
delivered escalation rates, weighted by commodity and transportation, to 1998
weighted average base year prices by sulfur level.
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EXHIBIT 36 AVG. DELIVERED COAL PRICE FORECAST FOR PJM BY SULFUR GRADE (1998 $)
- --------------------------------------------------------------------------------
[CHART]
- --------------------------------------------------------------------------------
URANIUM
Pace expects uranium prices to remain constant in real terms over the next 13
years. Therefore, Pace assumed utility uranium prices would be equal to their
1998 average value (0.00 % annual real rate of escalation).
EXISTING GENERATING CAPACITY PROFILES
Pace reviewed and assessed the existing and expected power generation resource
mix, the operational characteristics of capacity in PJM, and the cost profile of
existing units.
EXISTING UNIT COST PROFILE
For characterization of existing capacity, Pace utilized plant and unit specific
data for 1998 as reported to FERC and the EIA detailing variable O&M, fixed O&M,
fuel costs (adjusted for market delivered prices), capital expenditures, heat
rate efficiency, and summer and winter capacity. Given that capital costs are
not reported at the plant level, Pace has developed a methodology for allocating
utility-level embedded costs to each major power plant in the region.
Pace expects that variable and fixed O&M will remain constant over the 20 year
forecast period. Further, in order to maintain a level of conservativeness
underlying the Base Case Pace did not retire any existing units except for
nuclear capacity as detailed in the next section.
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NUCLEAR UNIT ASSESSMENT
Accounting for approximately 21% of installed capacity in PJM nuclear capacity
has a significant impact on the regional electric power markets and the expected
need for additional capacity into the future.
The nuclear industry has been subject to much uncertainty regarding future plant
operations. Specifically, the nuclear fleet must address issues associated with
design, cost, and re-licensing in order to establish future availability. While
license renewal remains an uncertainty for several plants in this and other
regions nationwide, the Calvert Cliffs nuclear facility in PJM is the first
nuclear facility in the US to receive license renewal. A final ruling on the
license application was issued by the Nuclear Regulatory Commission (NRC) on
March 23, 2000 and provides for license extension through 2034 and 2036 for
Units 1 and 2, respectively.
In addition, nuclear asset purchases have enjoyed significant attention from
market participants. Groups particularly active in nuclear tenders include
Entergy, AmerGen (a joint venture of PECO Energy and British Energy), and more
recently, Dominion Resources. Calling upon core competencies in nuclear asset
operations, these firms hope to decrease operating costs, increase plant margins
through pooling multiple nuclear assets, and ultimately, reduce costs associated
with decommissioning. However, it is currently unclear whether these and other
nuclear operators intend to expend significant capital to refurbish and maintain
these units past their license expiration or if they intend to decommission
these units when major investment is required.
Given the uncertainty surrounding the future of nuclear generation, Pace assumes
that all nuclear units in PJM will retire at their license expiration date.
Exhibit 37 provides a list of existing nuclear capacity located in PJM and the
current NRC license expiration date.
EXHIBIT 37: PJM NUCLEAR UNITS
- --------------------------------------------------------------------------------
---------------------------------------------------------------------------------------------------------------------------
SUMMER YEAR LICENSE
SUB- CAPACITY ORIGINALLY EXPIRATION/
REGION REGION PLANT NAME UNIT # OWNER (MW) CONSTRUCTED RETIREMENT
---------------------------------------------------------------------------------------------------------------------------
MAAC South Calvert Cliffs 1 BG&E 835 1975 2034
MAAC South Calvert Cliffs 2 BG&E 840 1977 2036
MAAC ACE Hope Creek 1 PSE&G and ACE 1,031 1987 2026
MAAC Northeast Limerick 1 PECO Energy Co. 1,155 1986 2024
MAAC Northeast Limerick 2 PECO Energy Co. 1,155 1990 2029
AmerGen Energy (PECO and British 619
MAAC Northeast Oyster Creek 1 Energy) 1969 2009
PECO Energy Co/PSE&G/ACE/ 1,093
MAAC Northeast Peach Bottom 2 Delmarva 1974 2013
PECO Energy Co/PSE&G/ACE/ 1,093
MAAC Northeast Peach Bottom 3 Delmarva 1974 2014
PECO Energy Co/PSE&G/ACE/ 1,106
MAAC Northeast Salem 1 Delmarva 1977 2016
PECO Energy Co/PSE&G/ACE/ 1,124
MAAC Northeast Salem 2 Delmarva 1981 2020
PP&L, Inc. and Allegheny Electric 1,090
MAAC Central Susquehanna 1 Coop, Inc. 1983 2022
PP&L, Inc. and Allegheny Electric 1,094
MAAC Central Susquehanna 2 Coop, Inc. 1985 2024
AmerGen Energy (PECO and British 786
MAAC Central Three Mile Island 1 Energy) 1974 2014
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
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EXPANSION GENERATING CAPACITY
NEW PLANT ANNOUNCEMENT ASSUMPTIONS
Developers have announced intentions to construct approximately 10,000 MW of
merchant capacity in PJM. Pace assessed each project's development status (i.e.,
permitting, financing, construction) through a review of trade press, regulatory
agency queuing, discussions with market participants, and information attained
through our activities in energy markets. Pace believes just over 4,600 MW of
this announced capacity has a strong potential of reaching commercial operation
in PJM. As detailed in Exhibit 38, Pace included those projects determined to
have a strong potential of reaching commercial operation in the Base Case.
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EXHIBIT 38: ANNOUNCED POWER PROJECTS IN PJM
- --------------------------------------------------------------------------------
PJM PROJECTS INCLUDED IN BASE CASE
PROJECT SUB- CAPACITY UNIT
COMPANY NAME REGION LOCATION STATE MW FUEL TYPE IN SERVICE COMMENTS
AES Corp. Red Oak Northeast Sayerville NJ 800 NG CC 2002 Permitting and finance
closing expected by
year-end 2000
AES Corp. Ironwood Central South Lebanon PA 700 NG CC 2001 Financing complete,
Township under construction
Enron Capital Linden Cogen Northeast Linden NJ 250 NG CC 2002 Under Development
and Trade
Resources
PG&E Generating Linden Northeast Linden NJ 1,100 NG CC 2003 Under Development;
Dupont Brownfield Site
with prelim siting
approvals in place
PG&E GENERATING MANTUA Northeast West Depford NJ 800 NG CC 2003 Under Development; has
CREEK received final Township
planning board siting
approval
PEI Power Corp. Archbald Central Archbald PA 70 Methane CT 2001 Under Construction;
broke ground in
November 1998
PECO Energy Muddy Run Northeast Muddy Run PA 104 Water Hydro 2001 Expansion to existing
hydro unit presently
under construction.
Commonwealth Accomack Southeast Accomack VA 312 Oil CT 2002 First phase of
Chesapeake Corp County construction commenced
of Norfolk August 1999.
Virginia
Calpine Ontelaunee Northeast Ontelaunee PA 545 NG CC 2003 Permitting application
Corporation Township filed June 1999 and
expect to break ground
in early 2000.
Purchased Westinghouse
501 F-D Turbines.
SUBTOTAL: 4,681
PJM PROJECTS NOT INCLUDED IN BASE CASE
Columbia Kelson Ridge Waldorf MD 550 NG CC 2001 County hearings on
Electric environmental impact
began 11/99.
Colombia Liberty Delaware PA 500 NG CC 2001 50/50 ownership split
Electric County
Westcoast Power
Panda Energy Hanover Hanover PA 1,000 NG CC 2002 Air permitting under
International Township process. EPC contractor
to be selected by April
2000.
Old Dominion Cecil County Cecil County MD 1,020 NG CT 2002 Filed permit
Electric application with
Cooperative Maryland PUC in August
1999
FPL Energy Marcus Hook Marcus Hook PA 725 NG CC 2002 Received community
Cogen council approval 1/2000
PP&L Global Martins Martins Creek PA 550 NG CC 2002
Creek
Williams Energy Hazleton Hazleton PA 250 NG CC 2000 Under Development,
Group Williams will act as
power marketer,
Repowering
SUBTOTAL: 4,595
GRAND TOTAL 9,276
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PROPRIETARY & CONFIDENTIAL
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EXPANSION UNIT CHARACTERISTICS AND COSTS
In evaluating potential generation technologies for meeting future demand
requirements in the region, Pace assessed each technology's maturity level,
operating history, and duty cycle. The region's existing power supply system is
comprised of an abundance of base-load power plants (e.g., coal, nuclear, and
hydro) and abundant intermediate and peaking capabilities.
Based on Pace's review of available generation technologies and consultation
with equipment manufacturers, three generic types of technologies were
designated as potential candidates for meeting future demand requirements for
purposes of this analysis:
- Pulverized Coal-Fired Capacity -- to meet base load requirements.
- Gas-Fired Combined Cycle -- to meet base load through intermediate
requirements.
- Gas-Fired Combustion Turbine -- to meet peak load requirements.
The characteristics of these standard units are detailed in Exhibit 39. These
expansion unit costs drive the expansion planning module to determine the
necessary capacity additions to meet projected demand and provide reserves with
the optimum mix of gas-fired combustion turbine, gas-fired combined cycle, and
coal-fired steam turbine capacity.
EXHIBIT 39: EXPANSION UNIT CHARACTERISTICS
- --------------------------------------------------------------------------------
- ---------------------------------------------------------------------------------
ITEM UNIT GAS CT GAS CC GAS CC COAL ST
- ---------------------------------------------------------------------------------
Model or Technology F G
- ---------------------------------------------------------------------------------
ASSUMPTIONS
Available Year Year 1999 1999 2005
Capacity MW 170 520 520 500
Installed Cost $/kW 325 525 536 1,050
Variable O&M $/MWh 3.50 1.75 1.75 1.75
Fixed O&M $/kW-yr 8.25 14.00 14.00 29.00
Heat Rate Btu/kWh 10,400 7,050 6,850 9,600
Percent Equity % 30 30 30 30
Interest Rate % 8.50 8.50 8.50 8.50
After Tax Return on
Equity % 15.00 15.00 15.00 15.00
Debt Term Years 15 15 15 15
Forced Outage % 2.5 2.5 2.5 2.5
Annual Maintenance Weeks 2.0 3.0 3.0 4.5
- ---------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
The expansion unit characteristics are assumed for standard construction
conditions. In areas where there are higher land values, labor costs, and other
potential cost adders, Pace increased the standard unit costs accordingly.
Pace's assumption of the high construction cost areas and their associated
adders are shown in Exhibit 40.
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EXHIBIT 40: HIGH CONSTRUCTION COST AREAS
- --------------------------------------------------------------------------------
- -------------------------------------------------------------
RESULTING INSTALLED COST ($/KW)
MULTIPLE OF --------------------------------
MODEL STANDARD COST CC CC
ZONE ASSUMPTION CT F G COAL
- -------------------------------------------------------------
Central 1.00 325 525 536 1,050
South 1.10 358 578 590 1,155
PJM-SE 1.10 358 578 590 1,155
ACE 1.15 374 604 616 1,208
PJM-NE 1.15 374 604 616 1,208
- -------------------------------------------------------------
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
PROPRIETARY & CONFIDENTIAL
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- --------------------------------------------------------------------------------
PACE GLOBAL ENERGY SERVICES, LLC
- --------------------------------------------------------------------------------
Pace Global Energy Services, LLC is an integrated energy consulting and
management company providing both strategic and transactional services to the
energy industry since 1979. Pace has extensive experience with the fuel and
power market evaluations both domestically and internationally. Pace provides a
unique level of experience and expertise in both the power and fuels markets.
Specifically, Pace provides our clients the following:
- Detailed and fundamental analysis of integrated power and fuel markets;
- A proven track record for comprehensive market price assessments for the
Northeast and other regions throughout the U.S. and internationally;
- Experience in power project financing and project due diligence support
of over 15,000 MW of projects;
- Real world gas and power transaction management experience nationwide and
specifically in the Northeast market area;
- Experience and perspective of working on behalf of developments,
industrials, and financial institutions during the development and
construction of energy projects;
- Multi-area market assessments considering transmission constrained power
trading;
- Risk management and market price volatility assessment and valuation;
- Optimization modeling and forecasts of energy and capacity markets.
- --------------------------------------------------------------------------------
PROPRIETARY & CONFIDENTIAL
A-45
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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 BONDS OR OUR
SOLICITATION OF YOUR OFFER TO BUY THE BONDS 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 , 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.
CEDAR BRAKES I, L.L.C.
$310,600,000
OFFER TO EXCHANGE ALL OUTSTANDING
8 1/2% SENIOR SECURED BONDS DUE 2014
FOR
8 1/2% SERIES B SENIOR SECURED BONDS DUE 2014
--------------------
PROSPECTUS
--------------------
, 2001
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
159
PART II
INFORMATION REQUIRED IN PROSPECTUS
ITEM 20. INDEMNIFICATION OF MANAGERS AND OFFICERS
Our limited liability company agreement provides that, except to the extent
expressly prohibited by the Delaware Limited Liability Company Act, we must
indemnify each person made or threatened to be made a party to any action or
proceeding, whether civil or criminal, by reason of the fact that the person or
the person's testator or intestate is or was our member or officer, against
judgments, fines (including excise taxes assessed on a person with respect to an
employee benefit plan), penalties, amounts paid in settlement and reasonable
expenses, including attorneys' fees, actually and necessarily incurred in
connection with such action or proceeding, or any appeal from such actions or
proceedings; provided that no indemnification will be made if a judgment or
other final adjudication adverse to the person establishes that his conduct did
not meet the then applicable minimum statutory standards of conduct; and
provided, further, that no indemnification will be required to any settlement or
other non-adjudicated disposition of any threatened or pending action or
proceeding unless we have given our prior consent to such settlement or such
other disposition, which consent will not be unreasonably withheld.
Section 18-108 of the Delaware Limited Liability Company Act states as
follows:
"Subject to such standards and restrictions, if any, as are set forth in
its limited liability company agreement, a limited liability company may, and
shall have the power to, indemnify and hold harmless any member or manager or
other person from and against any and all claims and demands whatsoever."
Insofar as indemnification for liabilities arising under the Securities Act
may be permitted to managers, officers or persons controlling us pursuant to the
foregoing, we have been informed that, in the opinion of the Securities and
Exchange Commission, such indemnification is against public policy as expressed
in the Securities Act and is, therefore, unenforceable.
ITEM 21. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) Exhibits
EXHIBIT
NO. DESCRIPTION
------- -----------
3.1* -- Certificate of Formation of Cedar Brakes I, L.L.C. dated
as of March 3, 2000.
3.2* -- Amended and Restated Limited Liability Company Agreement
of Cedar Brakes I, L.L.C. dated September 11, 2000.
3.3* -- Amendment No. 1, dated October 19, 2000, to Amended &
Restated Limited Liability Company Agreement of Cedar
Brakes I, L.L.C. dated September 11, 2000.
3.4* -- Amendment No. 2, dated January 19, 2001, to Amended and
Restated Limited Liability Company Agreement of Cedar
Brakes I, L.L.C., dated September 11, 2000.
4.1* -- Indenture dated as of September 26, 2000 between Cedar
Brakes I, L.L.C. and Bankers Trust Company, as Trustee.
4.2* -- First Supplemental Indenture dated as of November 20,
2000 between Cedar Brakes I, L.L.C. and Bankers Trust
Company, as Trustee.
4.2(a)* -- Second Supplemental Indenture dated as of January 19,
2001, between Cedar Brakes I, L.L.C., and Bankers Trust
Company, as Trustee.
4.3* -- Form of 8 1/2% Senior Secured Bonds due February 15,
2014.
II-1
160
EXHIBIT
NO. DESCRIPTION
------- -----------
4.4* -- Assignment and Security Agreement dated as of September
26, 2000 between Cedar Brakes I, L.L.C. and Bankers Trust
Company, as Trustee.
4.5* -- Accounts Control Agreement dated as of September 26, 2000
among Cedar Brakes I, L.L.C., Bankers Trust Company, as
Trustee, and Bankers Trust Company, as Securities
Intermediary.
4.6* -- Consent and Acknowledgment dated September 26, 2000 among
Cedar Brakes I, L.L.C., El Paso Energy Corporation and
Bankers Trust Company, as Trustee.
4.7* -- Consent and Acknowledgment dated September 26, 2000 among
Cedar Brakes I, L.L.C., El Paso Merchant Energy, L.P. and
Bankers Trust Company, as Trustee.
4.8* -- Consent and Acknowledgment dated September 26, 2000 among
the Company, Public Service Electric and Gas Company and
Bankers Trust Company, as Trustee.
4.9* -- Registration Rights Agreement dated as of September 20,
2000 between Cedar Brakes I, L.L.C. and Credit Suisse
First Boston, as Initial Purchaser.
5.1* -- Opinion of Chadbourne & Parke LLP as to the legality of
the bonds being registered hereby.
8.1 -- Opinion of Chadbourne & Parke LLP regarding tax matters.
10.1* -- Amended and Restated Power Purchase Agreement dated as of
March 21, 2000 between Cedar Brakes I, L.L.C. and Public
Service Electric and Gas Company.
10.2* -- Power Services Agreement dated September 20, 2000 between
Cedar Brakes I, L.L.C. and El Paso Merchant Energy, L.P.
10.3* -- Administrative Services Agreement dated as of September
20, 2000 between Cedar Brakes I, L.L.C. and El Paso
Merchant Energy, L.P.
10.4* -- Guaranty dated as of September 20, 2000 from El Paso
Energy Corporation of the performance of El Paso Merchant
Energy, L.P. under the Power Services Agreement (included
as Exhibit 10.2 hereto) and the Administrative Services
Agreement (included as Exhibit 10.3 hereto).
10.5* -- Purchase Agreement dated as of September 20, 2000 between
Cedar Brakes I, L.L.C. and Credit Suisse First Boston
Corporation, as Initial Purchaser.
12.1 -- Statement Regarding Computation of Ratios.
23.1 -- Consent of PricewaterhouseCoopers LLP.
23.2* -- Consent of Pace Global Energy Services LLC.
23.3 -- Consent of Chadbourne & Parke LLP (included in Exhibit
8.1 hereto).
24.1* -- Power of Attorney (included on the signature pages of
this Registration Statement).
25.1* -- Statement of Eligibility of Trustee dated as of January
22, 2001 by Bankers Trust Company.
99.1* -- Form of Letter of Transmittal for the 8 1/2% Senior
Secured Bonds Due 2014.
99.2* -- Form of Notice of Guaranteed Delivery for the 8 1/2%
Senior Secured Bonds Due 2014.
99.3* -- Form of Letter to Holders.
II-2
161
EXHIBIT
NO. DESCRIPTION
------- -----------
99.4* -- Form of Letter to Clients.
99.5* -- Form of Letter to Registered Holders and Depositary Trust
Company Participants.
99.6* -- Guidelines for Certification of Taxpayer Identification
Number on Substitute Form W-9.
99.7* -- Form of Exchange Agent Agreement.
- ---------------
* Previously filed
ITEM 22. UNDERTAKINGS
(a) Insofar as indemnification for liabilities arising under the Securities
Act of 1933, as amended (the "Securities Act"), may be permitted to directors,
officers and controlling persons of the registrant pursuant to the foregoing
provisions, or otherwise, the registrant has been advised that, in the opinion
of the Securities and Exchange Commission, such indemnification is against
public policy as expressed in the Securities Act and is, therefore,
unenforceable. In the event that a claim for indemnification against such
liabilities (other than the payment by the registrant of expenses incurred or
paid by a director, officer or controlling person of the registrant in the
successful defense of any action, suit or proceeding) is asserted by such
director, officer or controlling person in connection with the securities being
registered, the registrant will, unless, in the opinion of its counsel, the
matter has been settled by controlling precedent, submit to a court of
appropriate jurisdiction the question whether such indemnification by it is
against public policy as expressed in the Securities Act and will be governed by
the final adjudication of such issue.
(b) The undersigned registrant hereby undertakes:
(1) to file, during any period in which offers or sales are being
made, a post-effective amendment to this registration statement;
(i) to include any prospectus required by Section 10(a)(3) of the
Securities Act of 1933;
(ii) to reflect in the prospectus any facts or events arising after
the effective date of the registration statement (or the most recent
post-effective amendment thereof) which, individually or in the
aggregate, represent a fundamental change in the information set forth
in the registration statement. Notwithstanding the foregoing, any
increase or decrease in volume of securities offered (if the total
dollar value of securities offered would not exceed that which was
registered) and any deviation from the low or high end of the estimated
maximum offering range may be reflected in the form of prospectus filed
with the Commission pursuant to Rule 424(b) if, in the aggregate, the
changes in volume and price represent no more than 20 percent change in
the maximum aggregate offering price set forth in the "Calculation of
Registration Fee" table in the effective registration statement;
(iii) to include any material information with respect to the plan
of distribution not previously disclosed in the registration statement
or any material change to such information in the registration
statement;
(2) that, for the purpose of determining any liability under the
Securities Act of 1933, each such post-effective amendment shall be deemed
to be a new registration statement relating to the securities offered
therein, and the offering of such securities at that time shall be deemed
to be the initial bona fide offering thereof;
(3) to remove from registration by means of a post-effective amendment
any of the securities being registered which remain unsold at the
termination of the offering;
(4) that prior to any public reoffering of the securities registered
hereunder through use of a prospectus which is a part of this registration
statement, by any person or party who is deemed to be an
II-3
162
underwriter within the meaning of Rule 145(c), the issuer undertakes that
such reoffering prospectus will contain the information called for by the
applicable registration form with respect to reofferings by persons who may
be deemed underwriters, in addition to the information called for by the
other Items of the applicable form;
(5) that every prospectus (i) that is filed pursuant to paragraph (4)
immediately preceding, or (ii) that purports to meet the requirements of
Section 10(a)(3) of the Securities Act and is used in connection with an
offering of securities subject to Rule 415 (section 230.415 of this
chapter), will be filed as a part of an amendment to the registration
statement and will not be used until such amendment is effective, and that,
for purposes of determining any liability under the Securities Act, each
such post-effective amendment shall be deemed to be a new registration
statement relating to the securities offered therein, and the offering of
such securities at that time shall be deemed to be the initial bona fide
offering thereof;
(6) to respond to requests for information that is incorporated by
reference into this prospectus pursuant to Items 4, 10(b), 11 or 13 of this
Form, within one business day of receipt of such request, and to send the
incorporated documents by first class mail or other equally prompt means.
This includes information contained in documents filed subsequent to the
effective date of the registration statement through the date of responding
to the request; and
(7) to supply by means of a post-effective amendment all information
concerning a transaction, and the company being acquired involved therein,
that was not the subject of and included in the registration statement when
it became effective.
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163
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, as amended, the
Registrant has duly caused this Amendment No. 2 to the Registration Statement to
be signed on its behalf by the undersigned, thereunto duly authorized, in the
City of Houston, Texas, on March 29, 2001.
CEDAR BRAKES I, L.L.C.
By: /s/ JOHN L. HARRISON
----------------------------------
Name: John L. Harrison
Title: Vice President, Senior
Managing
Director and Class A
Manager
Pursuant to the requirements of the Securities Act of 1933, as amended,
this Amendment No. 2 to the Registration Statement has been signed by the
following persons in the capacities and on the dates indicated:
SIGNATURE TITLE DATE
--------- ----- ----
/s/ CLARK C. SMITH President March 29, 2001
- -----------------------------------------------------
Clark C. Smith
/s/ JOHN L. HARRISON Vice President, Senior March 29, 2001
- ----------------------------------------------------- Managing Director and Class
John L. Harrison A Manager (Principal
Financial Officer)
* Vice President, Managing March 29, 2001
- ----------------------------------------------------- Director and Controller
Cecilia T. Heilmann (Chief Accounting Officer)
* Class A Manager March 29, 2001
- -----------------------------------------------------
Kurt Regulski
* Class A Manager March 29, 2001
- -----------------------------------------------------
Timothy Sullivan
*By: /s/ H. BRENT AUSTIN
------------------------------------------------
H. Brent Austin
Attorney-in-fact
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164
INDEX TO EXHIBITS
EXHIBIT
NO. DESCRIPTION
------- -----------
3.1* -- Certificate of Formation of Cedar Brakes I, L.L.C. dated
as of March 3, 2000.
3.2* -- Amended and Restated Limited Liability Company Agreement
of Cedar Brakes I, L.L.C. dated September 11, 2000.
3.3* -- Amendment No. 1, dated October 19, 2000, to Amended &
Restated Limited Liability Company Agreement of Cedar
Brakes I, L.L.C. dated September 11, 2000.
3.4* -- Amendment No. 2, dated January 19, 2001, to Amended and
Restated Limited Liability Company Agreement of Cedar
Brakes I, L.L.C., dated September 11, 2000.
4.1* -- Indenture dated as of September 26, 2000 between Cedar
Brakes I, L.L.C. and Bankers Trust Company, as Trustee.
4.2* -- First Supplemental Indenture dated as of November 20,
2000 between Cedar Brakes I, L.L.C. and Bankers Trust
Company, as Trustee.
4.2(a)* -- Second Supplemental Indenture dated as of January 19,
2001, between Cedar Brakes I, L.L.C., and Bankers Trust
Company, as Trustee.
4.3* -- Form of 8 1/2% Senior Secured Bonds due February 15,
2014.
4.4* -- Assignment and Security Agreement dated as of September
26, 2000 between Cedar Brakes I, L.L.C. and Bankers Trust
Company, as Trustee.
4.5* -- Accounts Control Agreement dated as of September 26, 2000
among Cedar Brakes I, L.L.C., Bankers Trust Company, as
Trustee, and Bankers Trust Company, as Securities
Intermediary.
4.6* -- Consent and Acknowledgment dated September 26, 2000 among
Cedar Brakes I, L.L.C., El Paso Energy Corporation and
Bankers Trust Company, as Trustee.
4.7* -- Consent and Acknowledgment dated September 26, 2000 among
Cedar Brakes I, L.L.C., El Paso Merchant Energy, L.P. and
Bankers Trust Company, as Trustee.
4.8* -- Consent and Acknowledgment dated September 26, 2000 among
the Company, Public Service Electric and Gas Company and
Bankers Trust Company, as Trustee.
4.9* -- Registration Rights Agreement dated as of September 20,
2000 between Cedar Brakes I, L.L.C. and Credit Suisse
First Boston, as Initial Purchaser.
5.1* -- Opinion of Chadbourne & Parke LLP as to the legality of
the bonds being registered hereby.
8.1 -- Opinion of Chadbourne & Parke LLP regarding tax matters.
10.1* -- Amended and Restated Power Purchase Agreement dated as of
March 21, 2000 between Cedar Brakes I, L.L.C. and Public
Service Electric and Gas Company.
10.2* -- Power Services Agreement dated September 20, 2000 between
Cedar Brakes I, L.L.C. and El Paso Merchant Energy, L.P.
10.3* -- Administrative Services Agreement dated as of September
20, 2000 between Cedar Brakes I, L.L.C. and El Paso
Merchant Energy, L.P.
165
EXHIBIT
NO. DESCRIPTION
------- -----------
10.4* -- Guaranty dated as of September 20, 2000 from El Paso
Energy Corporation of the performance of El Paso Merchant
Energy, L.P. under the Power Services Agreement (included
as Exhibit 10.2 hereto) and the Administrative Services
Agreement (included as Exhibit 10.3 hereto).
10.5* -- Purchase Agreement dated as of September 20, 2000 between
Cedar Brakes I, L.L.C. and Credit Suisse First Boston
Corporation, as Initial Purchaser.
12.1 -- Statement Regarding Computation of Ratios.
23.1 -- Consent of PricewaterhouseCoopers LLP.
23.2* -- Consent of Pace Global Energy Services LLC.
23.3 -- Consent of Chadbourne & Parke LLP (included in Exhibit
8.1 hereto).
24.1* -- Power of Attorney (included on the signature pages of
this Registration Statement).
25.1* -- Statement of Eligibility of Trustee dated as of January
22, 2001 by Bankers Trust Company.
99.1* -- Form of Letter of Transmittal for the 8 1/2% Senior
Secured Bonds Due 2014.
99.2* -- Form of Notice of Guaranteed Delivery for the 8 1/2%
Senior Secured Bonds Due 2014.
99.3* -- Form of Letter to Holders.
99.4* -- Form of Letter to Clients.
99.5* -- Form of Letter to Registered Holders and Depositary Trust
Company Participants.
99.6* -- Guidelines for Certification of Taxpayer Identification
Number on Substitute Form W-9.
99.7* -- Form of Exchange Agent Agreement.
- ---------------
* Previously filed