CEDAR BRAKES I LLC - 10-Q Quarterly Report

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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

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FORM 10-Q

(MARK ONE)

[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2002

OR

[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM TO

COMMISSION FILE NUMBER 333-50828

CEDAR BRAKES I, L.L.C.
(Exact Name of Registrant as Specified in its Charter)

DELAWARE 76-0613853
(State or Other Jurisdiction (I.R.S. Employer
of Incorporation or Organization) Identification No.)

EL PASO BUILDING
1001 LOUISIANA STREET
HOUSTON, TEXAS 77002
(Address of Principal Executive Offices) (Zip Code)

Registrant's Telephone Number, Including Area Code: (713) 420-2600

Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No [ ]

As of November 12, 2002, 100 percent of the membership interest of Cedar
Brakes I, L.L.C. is owned directly by Mesquite Investors, L.L.C. Such membership
interest is not publicly traded and therefore has no separate, quantifiable
market value.

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PART I -- FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CEDAR BRAKES I, L.L.C.

CONDENSED STATEMENTS OF OPERATIONS
(IN THOUSANDS)
(UNAUDITED)

See accompanying notes.

1

CEDAR BRAKES I, L.L.C.

CONDENSED BALANCE SHEETS
(IN THOUSANDS)
(UNAUDITED)

See accompanying notes.

2

CEDAR BRAKES I, L.L.C.

CONDENSED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
(UNAUDITED)

See accompanying notes.

3

CEDAR BRAKES I, L.L.C.

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

1. BASIS OF PRESENTATION

We are a single member Delaware limited liability company organized in
March 2000, under the terms of a limited liability company agreement. We are a
wholly owned subsidiary of Mesquite Investors, L.L.C., an entity which is
indirectly owned by the Limestone Electron Trust and a subsidiary of El Paso
Corporation. We began operations on September 27, 2000 when we acquired a
long-term power purchase agreement to sell electric energy and provide electric
capacity to Public Service Electric and Gas Company.

We prepared this Quarterly Report on Form 10-Q under the rules and
regulations of the United States Securities and Exchange Commission. Because
this is an interim period filing presented using a condensed format, it does not
include all of the disclosures required by generally accepted accounting
principles. You should read it along with our 2001 Annual Report on Form 10-K
which includes a summary of our significant accounting policies and other
disclosures. The financial statements as of September 30, 2002, and for the
quarters and nine months ended September 30, 2002 and 2001, are unaudited. We
derived the balance sheet as of December 31, 2001 from the audited balance sheet
filed in our 2001 Form 10-K. We believe we have made all adjustments, all of
which are of a normal, recurring nature, to fairly present our interim period
results. Due to the seasonal nature of our business, information for interim
periods may not necessarily indicate the results of operations for the entire
year.

Our accounting policies are consistent with those discussed in our 2001
Form 10-K, except as discussed below.

ACCOUNTING FOR POWER PURCHASE AND POWER SERVICES AGREEMENTS

We record our power purchase and power services agreements on our balance
sheet at their estimated fair values in accordance with Statement of Financial
Accounting Standards (SFAS) No. 133, Accounting for Derivative Instruments and
Hedging Activities, as amended. We estimate the fair value of our power purchase
agreement with Public Service Electric and our power services agreement with El
Paso Merchant Energy, L.P., our affiliate, based on an estimate of the cash
receipts and payments under these agreements using anticipated future power
prices compared to the contractual prices under these agreements, discounted at
a rate that is based upon the 10-year United States Treasury rate, adjusted for
the credit risk of each counterparty.

We make adjustments to this discount rate when we believe that market
changes in the rates result in changes in fair values that can be realized. We
consider whether changes in the rates are the result of changes in the capital
markets, or are the result of sustained economic changes. During the third
quarter, treasury rates declined. We did not adjust our discount rate for this
decline in treasury rates since this decrease, combined with the significant
uncertainties in the capital markets, did not result in an increased fair value
that we believe could have been realized in the market.

In June 2002, we revised our power agreement discount rates as a result of
revised counterparty credit spreads and significant declines in the 10-year
Treasury rate from the time the initial fair value of the agreements were
estimated. As of September 30, 2002, the discount rate used to calculate the
fair value of the power purchase agreement was 6.44 percent and the rate used to
calculate the fair value of the power services agreement was 7.63 percent.

Our estimates of the timing of cash receipts and payments are based on the
anticipated timing of power delivered under these agreements. These estimates
also consider the minimum and maximum energy delivery requirements under our
agreements. Estimates of the future prices of power are based on the forward
pricing curve of the appropriate power delivery and receipt points, and this
curve is derived from actual prices observed in the market, price quotes from
brokers and extrapolation models that rely on actively quoted prices

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and historical information. Changes in these values in the future, which could
be positive or negative, will occur as our estimates of each of these variables
change and as additional market data becomes available, and these changes could
be material from period to period. However, the pricing of our power agreements
is fixed over their term and, as a result, despite short-term fluctuations in
market factors, our long-term reported results will be more reflective of the
terms of these agreements. If significant future changes in interest rates or
counterparty credit risks occur, it will have a significant impact on our
financial position and results of operations.

NEW ACCOUNTING PRONOUNCEMENTS

Goodwill and Other Intangible Assets

In July 2001, the Financial Accounting Standards Board (FASB) issued SFAS
No. 142, Goodwill and Other Intangible Assets. This standard requires that
goodwill no longer be amortized but periodically tested for impairment, at least
on an annual basis, or whenever an event occurs to indicate that an impairment
may have occurred. Other intangible assets are to be amortized over their useful
life and reviewed for impairment in accordance with the provisions of SFAS No.
144, Accounting for the Impairment or Disposal of Long-Lived Assets. An
intangible asset with an indefinite useful life can no longer be amortized until
its useful life becomes determinable. This statement has various effective
dates, the most significant of which is January 1, 2002. The adoption of this
standard on January 1, 2002 did not have a material effect on our financial
statements.

NEW ACCOUNTING PRONOUNCEMENTS ISSUED BUT NOT YET ADOPTED

Reporting Gains and Losses from the Early Extinguishment of Debt

In April 2002, the FASB issued SFAS No. 145, Rescission of FASB Statements
No. 4, 44, and 64, Amendment of FASB Statement No. 13, and Technical
Corrections. This statement addresses how to report gains or losses resulting
from the early extinguishment of debt. Under current accounting rules, any gains
or losses on early extinguishment of debt are reported as an extraordinary item.
When we adopt SFAS No. 145, we will be required to evaluate whether any debt
extinguishment is truly extraordinary in nature. If we routinely extinguish debt
early, the gain or loss will be included in income from continuing operations.
This statement will be effective for our 2003 year-end reporting.

Accounting for Costs Associated with Exit or Disposal Activities

In July 2002, the FASB issued SFAS No. 146, Accounting for Costs Associated
with Exit or Disposal Activities. This statement will require us to recognize
costs associated with exit or disposal activities when they are incurred rather
than when we commit to an exit or disposal plan. Examples of costs covered by
this guidance include lease termination costs, employee severance costs that are
associated with a restructuring, discontinued operations, plant closings, or
other exit or disposal activities. The provisions of this statement are
effective for fiscal years beginning after December 31, 2002 and will impact any
exit or disposal activities initiated after January 1, 2003.

2. COMMITMENTS AND CONTINGENCIES

Power Purchase Agreement

We have a power purchase agreement with Public Service Electric that
extends through August 2013. Under this agreement, we are required to arrange
for 123 megawatts per day of electric capacity to be made available to Public
Service Electric, and we are required to sell and deliver electric energy to
Public Service Electric at established prices and at any delivery point within
the Pennsylvania-New Jersey-Maryland power system. The prices under the
agreement are specified on an annual basis and escalate each year over the
contract term. For 2001, the price was $72.17 per megawatt hour and, for 2002,
the price is $73.53 per megawatt hour, increasing annually to $92.43 per
megawatt hour in 2013. The amount of energy delivered under this agreement is
subject to an annual minimum and maximum requirement. We must deliver a minimum
of 394,000 megawatt hours of on-peak electric energy annually, with 40,000
megawatt hours

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required in each of the months of June through September during the on-peak
hours. The remainder of the minimum requirements must be met during the other
months in the year. During any one year, total deliveries cannot exceed the
specified maximum amounts, which range from 788,954 megawatt hours to 855,779
megawatt hours over the life of the agreement.

If we fail to deliver all or part of the scheduled energy or fail to
schedule sufficient deliveries to meet the minimum energy delivery requirements
for reasons within our control, Public Service Electric's payment to us may be
reduced by a credit, if any, for energy purchased by Public Service Electric
over the prices stated in our power purchase agreement. No credits were applied
during the nine months ended September 30, 2002 or 2001.

If we fail to provide all or part of the required electric capacity for
reasons within our control, 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 power purchase agreement. Generally, the credit would equal
the deficiency charge, if any, payable by Public Service Electric as a direct
result of our failure to provide the required electric capacity. No credits were
applied during the nine months ended September 30, 2002 or 2001.

Power Services Agreement

In order to meet our electric energy delivery and electric capacity
commitments under the power purchase agreement, we entered into a power services
agreement with El Paso Merchant. The power services agreement has the same term
as the power purchase agreement. Under this agreement, we purchase energy at an
established price and at quantities sufficient to meet our obligations to Public
Service Electric. The prices under the power services agreement were $29.71 per
megawatt hour in 2001, and are $29.30 per megawatt hour in 2002. Beyond 2002,
these prices escalate each year to $33.75 per megawatt hour in 2013.

Under the power services agreement, El Paso Merchant must schedule and
deliver to us during each year both the minimum hourly energy deliveries and the
full amount of energy deliveries that we are obligated to deliver under our
power purchase agreement with Public Service Electric and El Paso Merchant must
also make available to us capacity credits equal to the capacity we are required
to provide under our power purchase agreement with Public Service Electric. If
El Paso Merchant fails to deliver all or part of the scheduled energy to us for
any reason within their control, our payment to them will be reduced by a credit
calculated in the same manner as the credit to Public Service Electric described
above. No credits were taken during the nine months ended September 30, 2002 and
2001.

The power services agreement also requires that El Paso Merchant provide
sufficient amounts of electric capacity to meet our capacity requirements under
the power purchase agreement. If El Paso Merchant fails to provide all or part
of the capacity, for any reason within their control, our payment to them will
be reduced by a credit calculated in the same manner as our payment to Public
Service Electric if we fail to provide capacity under the power purchase
agreement. No credits were taken during the nine months ended September 30, 2002
and 2001. El Paso Merchant's performance under this agreement has been
guaranteed by El Paso Corporation under a performance guaranty.

Because our power purchase and power services agreements are similar in
terms of the amount of capacity provided and the quantities of electric energy
bought and sold, and since prices under these agreements are established, the
execution of these agreements results in our ability to receive a determinable
cash margin over the term of the agreements. Assuming that minimum electric
energy delivery requirements are met and all electric capacity requirements are
made available, this margin will range from $44.23 to $59.99 per megawatt hour
sold over the remaining life of the agreements.

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3. RELATED PARTY TRANSACTIONS

Power Services Agreement

El Paso Merchant provides electric energy and electric capacity to us under
the power services agreement as discussed above. Purchases under this agreement
are based on market rates at the time the agreement was negotiated. Total
purchases during 2002 and 2001 are reflected as electricity
purchases -- affiliate in our statements of operations. Amounts owed under the
agreement are included in accounts payable -- affiliate on our balance sheets.

Administrative Services Agreement

We have 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 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. Total
fees incurred under this agreement during 2002 and 2001 are reflected as
administrative fees to affiliate in our statements of operations.

El Paso Corporation Performance Guaranty

El Paso Corporation, the parent company of El Paso Merchant, entered into a
performance guaranty with us on September 27, 2000, which expires after the
expiration of El Paso Merchant's obligations under the power services and
administrative services agreement. Under the performance guaranty, El Paso
Corporation guarantees to us the punctual performance of all of El Paso
Merchant's obligations under the power services agreement and administrative
services agreement.

Distributions

As permitted by the senior secured bond indenture and our limited liability
company agreement, cash distributions may be made to our member on February 15
of each year for all excess cash, provided that no event of default or defaults
have occurred and the debt coverage ratio calculated as of that date for the
most recently ended six-month period equals or exceeds 1.03 to 1.00. A
distribution of $1.2 million was paid to our member during February 2002.

El Paso Corporation Announces Exit of Energy Trading Activities

On November 8, 2002, El Paso Corporation announced its plan to exit the
energy trading business. El Paso's plan includes forming a new subsidiary to
hold, manage and liquidate its trading assets and liabilities currently held by
its 100% owned subsidiary and our affiliate, El Paso Merchant Energy, L.P. Our
indenture requires the consent of the lenders to an assignment by El Paso
Merchant of its obligations under our power services agreement. El Paso
Corporation has guaranteed to us the punctual performance of all of El Paso
Merchant's obligations under the power services and administrative services
agreements. We are in the process of evaluating what impact, if any, this
announcement will have on these agreements.

4. FAIR VALUE OF FINANCIAL INSTRUMENTS

As of September 30, 2002 and December 31, 2001, 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 nature.
The fair value of our long-term debt was $236.1 million as of September 30,
2002, and $337.0 million as of December 31, 2001. The fair value of our
long-term debt has been estimated based on quoted market prices for the same or
similar issues.

In May 2002, Standard and Poor's lowered the senior unsecured credit rating
of our only customer, Public Service Electric, from BBB+ to BBB-. Although our
credit rating is not directly related to the credit rating of Public Service
Electric, an indirect result of this downgrade was a reduction in the credit
rating of our bonds in June 2002 by Standard and Poor's from BBB to BBB-.
Further downgrades of Public Service Electric could indirectly have a negative
impact on the fair value of our long-term debt.

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On October 4, 2002, Moody's Investors Service downgraded our debt rating to
Baa3 from Baa2. This downgrade reflects previous action taken by Moody's on the
ratings of El Paso Corporation which guarantees El Paso Merchant's performance
under our power services agreement. On November 12, 2002, action was taken by
Standard and Poor's which resulted in a downgrade to El Paso Corporation's
credit ratings. This and further downgrades of El Paso Corporation's credit
ratings could indirectly have a negative impact on the fair value of our
long-term debt.

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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS

The information contained in Item 2 updates, and you should read it in
conjunction with, information disclosed in our 2001 Form 10-K dated March 26,
2002, in addition to the financial statements and notes presented in Item 1 of
this Quarterly Report on Form 10-Q.

RECENT DEVELOPMENTS

El Paso Corporation Announces Exit of Energy Trading Activities

On November 8, 2002, El Paso Corporation announced its plan to exit the
energy trading business. El Paso's plan includes forming a new subsidiary to
hold, manage and liquidate its trading assets and liabilities currently held by
its 100% owned subsidiary and our affiliate, El Paso Merchant Energy, L.P. Our
indenture requires the consent of the lenders to an assignment by El Paso
Merchant of its obligations under our power services agreement. El Paso
Corporation has guaranteed to us the punctual performance of all of El Paso
Merchant's obligations under the power services and administrative services
agreements. We are in the process of evaluating what impact, if any, this
announcement will have on these agreements.

Potential Changes in Mesquite Investors' Ownership

On November 8, 2002, El Paso Corporation announced its intent to acquire an
additional interest in Chaparral Investors, L.L.C. Chaparral owns Mesquite
Investors, L.L.C., our parent company. Chaparral is owned approximately 20% by
El Paso and the remainder by Limestone Investors, L.L.C. If El Paso acquires
Limestone's interests, we would become a wholly-owned, indirect subsidiary of El
Paso.

GENERAL

Power Contract Restructurings

Our sole business is to sell electric energy and provide electric capacity
to Public Service Electric under our power purchase agreement with them. We were
formed in March 2000, but did not begin operations until September 27, 2000 when
we acquired a power purchase agreement from our affiliate, Newark Bay
Cogeneration Partnership L.P. This power purchase agreement was acquired as part
of the process of what has become known in the power industry as a "power
contract restructuring." Many domestic power plants have long-term power sales
contracts with regulated utilities that were entered into under the Public
Utility Regulatory Policies Act of 1978 (PURPA). The power sold to the utility
under these PURPA contracts is required to be delivered from a specified power
generation plant at power prices that are usually significantly higher than the
cost of power in the wholesale power market. The cost of generating power at
these PURPA power plants is typically higher than the cost that would be
incurred by obtaining the power in the wholesale power market, principally
because the PURPA power plants are less efficient than newer power generation
facilities.

In a power contract restructuring, the PURPA power purchase agreement is
amended so that the power sold to the utility does not have to be provided from
the specific power plant. Because we are able to buy lower cost power in the
wholesale power market, we have the ability to reduce the cost paid by the
utility, thereby inducing the utility to enter into the power contract
restructuring transaction. Following the contract restructuring, the power plant
operates on a merchant basis, which means that it is no longer dedicated to one
buyer and will operate only when power prices are high enough to make operations
economical. Prior to a power contract restructuring, the power plant and its
related PURPA power purchase agreement are accounted for at their historical
cost, which is either the cost of construction or, if acquired, the acquisition
cost. Revenues and expenses prior to restructuring are, in most cases, accounted
for on an accrual basis as power is generated and sold to the utility. As part
of the restructuring, any related fuel supply and steam contracts are generally
amended or terminated, the value of the remaining merchant plant is evaluated
for possible impairment, and the restructured power purchase agreements are
adjusted to their estimated fair value. The restructured power agreement can
then be sold or we can enter into an offsetting power services agreement. In
cases when we enter into a power services agreement, we use the restructured
power purchase agreement and the power services agreement, along with the
fixed-price spread between these contracts as
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collateral to obtain financing. The offsetting power services agreement requires
the power supplier, which can be an affiliate or third-party, to provide
long-term fixed price power in amounts sufficient for us to meet our obligations
under the restructured power agreement.

Under the original power purchase agreement, Newark Bay sold generating
capacity and associated energy from the Newark Bay facility to Public Service
Electric and the Newark Bay facility was required to be a qualifying facility
under PURPA. Newark Bay and Public Service Electric sought to amend the original
power purchase agreement in order to achieve a number of benefits, including the
elimination of the requirement that the capacity and energy sold under the
original power purchase agreement be sourced only from the Newark Bay facility.
The elimination of this requirement benefited us because now we can source
energy from any source connected to the Pennsylvania-New Jersey-Maryland (PJM)
market, and the cost of energy sourced in this manner 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. From the perspective of Public Service Electric, our ability to
source lower cost power in the market allowed us to provide Public Service
Electric with a substantial reduction in the price of the energy and capacity
rates under the amended power purchase agreement compared to the prices under
the original power purchase agreement.

We purchased the original power purchase agreement from Newark Bay on
September 27, 2000, for $289.8 million. We simultaneously amended the original
power purchase agreement and began operating under the restructured power
purchase agreement on September 27, 2000. In order to meet our energy delivery
and electric capacity commitments under the power purchase agreement, we entered
into a power services agreement with El Paso Merchant. The power services
agreement has the same term as the power purchase agreement and we purchase
energy at an established price and at quantities sufficient to meet our
obligations to Public Service Electric.

In September 2000, we issued 8 1/2% Series A Senior Secured Bonds, due
2014, with an aggregate principal amount of $310.6 million. We completed an
exchange of the Series A bonds for registered 8 1/2% Series B Senior Secured
Bonds, due 2014, in May 2001. 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 are registered with the Securities and Exchange Commission.
Scheduled payments of principal and interest on the bonds are expected to be
paid from the positive margin created between the sales of electric energy and
capacity to Public Service Electric and purchases of electric energy and
capacity from El Paso Merchant.

The power purchase agreement was initially accounted for as an intangible
asset, which we amortized ratably as we recognized revenues under the agreement.
Beginning January 1, 2001, our power purchase agreement and our power services
agreement were accounted for as derivative instruments under the provisions of
SFAS No. 133. As a result, the power purchase agreement and the power services
agreement were recorded on our balance sheet at their estimated fair values,
with changes in those estimated fair values recorded in our statement of
operations. The difference between the fair value and the unamortized cost of
these agreements on January 1, 2001, was $89.4 million, and was recorded as a
cumulative effect of an accounting change in our statement of operations.

As of September 30, 2002, these agreements had an estimated net fair value
of $341.9 million. For the nine months ended September 30, 2002, the change in
estimated net fair value of these agreements was an increase of $14.7 million
and was recorded as a component of operating expenses in our condensed statement
of operations. The fair values of these agreements are calculated based on
expected cash receipts and payments under the agreements compared to the
estimated future market prices of power. These estimated market prices for power
consider a combination of available market data, broker quotations and models
that are derived based on historical market prices. The differences between
market and contractual prices are then discounted using discount rates that
consider the counterparty credit risk and current and anticipated market
conditions. We make adjustments to this discount rate when we believe that
market changes in the rates result in changes in fair values that can be
realized. We consider whether changes in the rates are the result of changes in
the capital markets, or are the result of sustained economic changes. During the
third quarter, treasury rates declined. We did not adjust our discount rate for
this decline in treasury rates since this

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decrease, combined with the significant uncertainties in the capital markets,
did not result in an increased fair value that we believe could have been
realized in the market. As of September 30, 2002, the discount rate used to
calculate the fair value of the power purchase agreement was 6.44 percent and
the rate used to calculate the fair value of the power services agreement was
7.63 percent.

We also adjust our valuations for factors such as market liquidity, market
price correlation and model risk, as needed. Future power prices are based on
the forward pricing curve of the appropriate power delivery and receipt points
in the applicable power market. This forward pricing curve is derived from a
combination of actual prices observed in the applicable market, price quotes
from brokers and extrapolation models that rely on actively quoted prices and
historical information. The timing of cash receipts and payments are based on
the expected timing of power delivered under these contracts.

RESULTS OF OPERATIONS

Third Quarter 2002 Compared to Third Quarter 2001

For the quarter ended September 30, 2002, we had net income of $0.5 million
compared to a net loss of $1.1 million for the quarter ended September 30, 2001.
During the third quarter of 2002, we generated operating revenues of $17.3
million from the sale of approximately 236,000 megawatt hours of electric energy
and from providing electric capacity to Public Service Electric compared to
revenues of $16.6 million from the sale of approximately 230,000 megawatt hours
of electric energy and providing electric capacity for the same period in 2001.
Operating expenses were approximately $10.1 million for the third quarter of
2002 and $11.0 million for the third quarter of 2001. The decrease was primarily
due to a decrease in the market value of our power agreements. Our operating
expenses also include fees incurred under our administrative services agreement
with El Paso Merchant. Interest and debt expense decreased to $6.8 million for
the quarter ended September 30, 2002 compared to $7.0 million for the same
period in the prior year primarily due to a lower outstanding principal balance
in 2002.

Nine Months Ended September 30, 2002 Compared to Nine Months Ended September 30,
2001

For the nine months ended September 30, 2002, we had net income of $24.5
million compared to net income of $83.4 million for the nine months ended
September 30, 2001. The September 30, 2001 amount includes income of $89.4
million as a result of our adoption of SFAS No. 133 on January 1, 2001.
Excluding this item, our net loss would have been $5.9 million. During the first
nine months of 2002, we generated operating revenues of $49.3 million from the
sale of approximately 670,000 megawatt hours of electric energy and from
providing electric capacity to Public Service Electric compared to revenues of
$47.0 million from the sale of approximately 653,000 megawatt hours of electric
energy and providing electric capacity for the same period in 2001. The decrease
in operating expenses from $33.4 million for the nine months ended September 30,
2001 to $5.2 million for the nine months ended September 30, 2002 was primarily
driven by changes in the fair value of our power agreements. The fair value of
our power purchase agreement changed primarily due to the June 2002 changes in
the risk-adjusted rate used to calculate the fair value of our power purchase
agreement. This change in the risk-adjusted rate resulted primarily from a
significant decline in long-term interest rates from the time the initial fair
value of the agreement was estimated. This change in estimate resulted in an
increase in the market value of power agreements on our statement of operations
of approximately $24.1 million. Our operating expenses also include fees
incurred under our administrative services agreement with El Paso Merchant.
Interest and debt expense decreased to $19.9 million for the nine months ended
September 30, 2002 compared to $20.2 million for the same period in 2001 due to
a lower outstanding principal balance in 2002.

LIQUIDITY AND CAPITAL RESOURCES

Cash from Operating Activities

Net cash used in operating activities was $3.1 million for the nine months
ended September 30, 2002 compared to net cash provided by operating activities
of $5.0 million for the same period in 2001. The

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decrease was primarily due to changes in working capital items, primarily August
revenues not collected until October 3, 2002, partially offset by increases in
electricity sales.

Cash from Financing Activities

Net cash used in financing activities was $6.8 million for the nine months
ended September 30, 2002 and consisted primarily of a $5.9 million principal
payment on our long-term debt made on February 15, 2002, and a $1.2 million
distribution to our sole member.

Distributions and Debt Service

Under our bond indenture, cash distributions may be made to our member on
February 15 of each year for all excess cash, provided that no event of default
or defaults have occurred and the debt coverage ratio calculated as of that date
for the most recently ended six-month period equals or exceeds 1.03 to 1.00. A
distribution of $1.2 million was paid to our member during February 2002. During
the six months ended January 31, 2002, we generated funds of approximately $15.7
million available for debt service from the sale of electric energy and electric
capacity. Interest for this period was approximately $13.2 million, providing an
interest coverage ratio of 1.19. Including the proportionate principal payments
for the same period of approximately $2.1 million, the debt service coverage
ratio was 1.03. During the nine months ended September 30, 2002, we generated
funds of approximately $29.7 million available for debt service from the sale of
electric energy and electric capacity. Interest for this period was
approximately $19.5 million, providing an interest coverage ratio of 1.53.
Including the proportionate principal payments for the same period of
approximately $5.7 million, the debt service coverage ratio was 1.18.

CAUTIONARY STATEMENT FOR PURPOSES OF THE "SAFE HARBOR" PROVISIONS OF THE PRIVATE
SECURITIES LITIGATION REFORM ACT OF 1995

This report contains or incorporates by reference forward-looking
statements within the meaning of the Private Securities Litigation Reform Act of
1995. Where any forward-looking statement includes a statement of the
assumptions or bases underlying the forward-looking statement, we caution that,
while we believe these assumptions or bases to be reasonable and to be made in
good faith, assumed facts or bases almost always vary from the actual results,
and the differences between assumed facts or bases and actual results can be
material, depending on the circumstances. Where, in any forward-looking
statement, we or our management express an expectation or belief as to future
results, that expectation or belief is expressed in good faith and is believed
to have a reasonable basis. We cannot assure you, however, that the statement of
expectation or belief will result or be achieved or accomplished. The words
"believe," "expect," "estimate," "anticipate" and similar expressions will
generally identify forward-looking statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

INTEREST RATE RISK

We are exposed to changing interest rates. The fair value of our long-term,
fixed rate debt was $236.1 million as of September 30, 2002 and $337.0 million
as of December 31, 2001. The fair value of our long-term debt was estimated
based on quoted market prices for the same or similar issues.

On October 4, 2002, Moody's Investors Service downgraded our debt rating to
Baa3 from Baa2. This downgrade reflects previous action taken by Moody's on the
ratings of El Paso Corporation which guarantees El Paso Merchant's performance
under our power services agreement. On November 12, 2002, action was taken by
Standard and Poor's which resulted in a downgrade to El Paso Corporation's
credit ratings. This and further downgrades of El Paso Corporation's credit
ratings could indirectly have a negative impact on the fair value of our
long-term debt.

Our power contracts are also sensitive to interest rates since the
anticipated cash flows from these contracts are discounted at a credit
risk-adjusted United States Treasury rate to arrive at their fair value.

12

Changes in these rates impact our fair value estimates. The sensitivity of the
fair value of our power agreements to changes in interest rates are as follows:

COMMODITY PRICE RISK

Our power purchase agreement and power services agreement meet the
definition of derivatives under the provisions of SFAS No. 133 and are carried
at their fair value. The fair value of these agreements at September 30, 2002,
was estimated considering the expected estimated cash receipts and payments
under these agreements using contractual prices under these agreements compared
to anticipated future power prices discounted at a risk-adjusted rate
commensurate with the term of each contract and the credit risk of the
counterparty. Our estimates of the timing of cash receipts and payments are
based on the anticipated timing of power delivery under these agreements. These
estimates also consider the minimum and maximum energy delivery requirements
under those agreements. Estimates of the future prices of power consider the
forward pricing curve of the appropriate power delivery and receipt points, and
this curve is derived from the actual prices observed in the market, price
quotes from brokers and extrapolation models that rely on actively, quoted
prices and historical information. Changes in future prices impact the fair
value of these contracts.

The sensitivity of the fair value of our power agreements to changes in
commodity prices is as follows:

ITEM 4. CONTROLS AND PROCEDURES

Under the supervision and with the participation of our management,
including our principal executive officer and principal financial officer, we
have evaluated the effectiveness of the design and operation of our disclosure
controls and procedures within 90 days of the filing date of this quarterly
report, pursuant to Rules 13a-15 and 15d-15 under the Securities Exchange Act of
1934 (the "Exchange Act"). Based on that evaluation, our principal executive
officer and principal financial officer have concluded that these controls and
procedures are effective. There were no significant changes in our internal
controls or in other factors that could significantly affect these controls
subsequent to the date of their evaluation.

Disclosure controls and procedures are our controls and other procedures
that are designed to ensure that information required to be disclosed by us in
the reports that we file or submit under the Exchange Act is recorded,
processed, summarized and reported, within the time periods specified under the
Exchange Act. Disclosure controls and procedures include, without limitation,
controls and procedures designed to ensure that information required to be
disclosed by us in the reports that we file under the Exchange Act is
accumulated and communicated to our management, including our principal
executive officer and principal financial officer, as appropriate to allow
timely decisions regarding required disclosure.

The principal executive officer and principal financial officer
certifications required under Sections 302 and 906 of the Sarbanes-Oxley Act of
2002 have been included herein, or as Exhibits to this Quarterly Report on Form
10-Q, as appropriate.

13

PART II -- OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY-HOLDERS

None.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

a. Exhibits

Each exhibit identified below is filed as part of this report. Exhibits not
incorporated by reference to a prior filing are designated by an "*"; all
exhibits not so designated are incorporated herein by reference to a prior
filing as indicated.

Undertaking

We hereby undertake, pursuant to Regulation S-K, Item 601(b),
paragraph (4)(iii), to furnish to the United States Securities and Exchange
Commission, upon request, all constituent instruments defining the rights
of holders of our long-term debt not filed herewith for the reason that the
total amount of securities authorized under any of such instruments does
not exceed 10 percent of our total consolidated assets.

b. Reports on Form 8-K

None.

14

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this Report to be signed on its behalf by the
undersigned thereunto duly authorized.

CEDAR BRAKES I, L.L.C.

Date: November 14, 2002 /s/ JOHN L. HARRISON
-----------------------------------------
John L. Harrison
Senior Vice President,
Chief Financial Officer,
Treasurer and
Class A Manager
(Principal Financial Officer)

Date: November 14, 2002 /s/ BRYAN E. SEAS
-----------------------------------------
Bryan E. Seas
Vice President and Controller
(Principal Accounting Officer)

15

CERTIFICATION

I, Clark C. Smith, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cedar Brakes I,
L.L.C.;

2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which such
statements were made, not misleading with respect to the period covered by
this quarterly report;

3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in this
quarterly report;

4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

a) designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those
entities, particularly during the period in which this quarterly report
is being prepared;

b) evaluated the effectiveness of the registrant's disclosure controls
and procedures as of a date within 90 days prior to the filing date of
this quarterly report (the "Evaluation Date"); and

c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on our
evaluation as of the Evaluation Date;

5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the audit
committee of registrant's board of directors (or persons performing the
equivalent function):

a) all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have identified
for the registrant's auditors any material weaknesses in internal
controls; and

b) any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal
controls; and

6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in internal
controls or in other factors that could significantly affect internal
controls subsequent to the date of our most recent evaluation, including
any corrective actions with regard to significant deficiencies and material
weaknesses.

Date: November 14, 2002
/s/ CLARK C. SMITH
----------------------------------------
Clark C. Smith
President
(Principal Executive Officer)
Cedar Brakes I, L.L.C.

16

CERTIFICATION

I, John L. Harrison, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cedar Brakes I,
L.L.C.;

2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which such
statements were made, not misleading with respect to the period covered by
this quarterly report;

3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in this
quarterly report;

4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

a) designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within those
entities, particularly during the period in which this quarterly report
is being prepared;

b) evaluated the effectiveness of the registrant's disclosure controls
and procedures as of a date within 90 days prior to the filing date of
this quarterly report (the "Evaluation Date"); and

c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on our
evaluation as of the Evaluation Date;

5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the audit
committee of registrant's board of directors (or persons performing the
equivalent function):

a) all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have identified
for the registrant's auditors any material weaknesses in internal
controls; and

b) any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal
controls; and

6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in internal
controls or in other factors that could significantly affect internal
controls subsequent to the date of our most recent evaluation, including
any corrective actions with regard to significant deficiencies and material
weaknesses.

Date: November 14, 2002
/s/ JOHN L. HARRISON
----------------------------------------
John L. Harrison
Senior Vice President,
Chief Financial Officer,
Treasurer and Class A Manager
(Principal Financial Officer)
Cedar Brakes I, L.L.C.

17

INDEX TO EXHIBITS

Each exhibit identified below is filed as part of this report. Exhibits not
incorporated by reference to a prior filing are designated by an "*"; all
exhibits not so designated are incorporated herein by reference to a prior
filing as indicated.