UNITED STATES SECURITIES AND EXCHANGE COMMISSION
 Washington, D.C. 20549
 ________________
  Form 10-Q
 (Mark One)
 
 R
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934For the quarterly period ended June 30, 2009OR£
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OFTHE SECURITIES EXCHANGE ACT OF 1934For the transition period from                                                      to
 
 Commission File Number 1-2700
 ________________
 El Paso Natural Gas Company
 (Exact Name of Registrant as Specified in Its Charter)
 
 Delaware
74-0608280(State or Other Jurisdictionof Incorporation or Organization)
(I.R.S. EmployerIdentification No.)El Paso Building1001 Louisiana Street
Houston, Texas
77002(Address of Principal Executive Offices)
(Zip Code)
 
 Telephone Number: (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 R   No £
 
 Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to
submit and post such files).  Yes £   No £
 
 Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the
Exchange Act.
 
 Large accelerated filer £           Accelerated filer £                  
Non-accelerated filer RSmaller reporting company £
 (Do not check if a smaller reporting company)
 
 Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes £ No R
 
 Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.
 
 Common stock, par value $1 per share. Shares outstanding on August 7, 2009: 1,000
 
 EL PASO NATURAL GAS COMPANY MEETS THE CONDITIONS OF GENERAL INSTRUCTION H(1)(a) AND (b) TO FORM 10-Q AND IS THEREFORE FILING THIS REPORT WITH A REDUCED
DISCLOSURE FORMAT AS PERMITTED BY SUCH INSTRUCTION.
 
 
 EL PASO NATURAL GAS COMPANY
 
 TABLE OF CONTENTS
 
 Caption
PagePART I — Financial InformationItem  1.
Financial Statements
1Item  2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
10Item  3.
Quantitative and Qualitative Disclosures About Market Risk
*Item  4.
Controls and Procedures
14PART II — Other InformationItem  1.
Legal Proceedings
15Item  1A.
Risk Factors
15Item  2.
Unregistered Sales of Equity Securities and Use of Proceeds
*Item  3.
Defaults Upon Senior Securities
*Item  4.
Submission of Matters to a Vote of Security Holders
*Item  5.
Other Information
15Item  6.
Exhibits
16Signatures
17
 ____________
 
 * We have not included a response to this item in this document since no response is required pursuant to the  reduced disclosure format permitted by General Instruction H to Form 10-Q.
 
 Below is a list of terms that are common to our industry and used throughout this document:
 
 /d
= per day
MDth
= thousand dekathermsBBtu
= billion British thermal units
Tonne
= metric ton
 
 
 When we refer to cubic feet measurements, all measurements are at a pressure of 14.73 pounds per square inch.
 
 When we refer to “us”, “we”, “our”, “ours” or “EPNG”, we are describing El Paso Natural Gas Company and/or our subsidiaries.
 i
 PART I — FINANCIAL INFORMATION
 
 Item 1. Financial Statements
 
 EL PASO NATURAL GAS COMPANY
 
 CONDENSED CONSOLIDATED STATEMENTS OF INCOME
 (In millions)
 (Unaudited)
 
 Quarter Ended
June 30,


Six Months Ended
June 30,2009


2008


2009


2008Operating revenues

$
144


$
152


$
301


$
293Operating expensesOperation and maintenance


49



51



96



104Depreciation and amortization


21



21



42



41Taxes, other than income taxes


7



6



15



1477



78



153



159Operating income


67



74



148



134Other income, net


—



2



1



3Interest and debt expense


(23
)


(22
)


(46
)


(45
)Affiliated interest income, net


5



11



10



26Income before income taxes


49



65



113



118Income taxes


19



25



43



45Net income

$
30


$
40


$
70


$
73
 
 See accompanying notes.
 
 
 1
 Table of Contents
 
 EL PASO NATURAL GAS COMPANY
 
 CONDENSED CONSOLIDATED BALANCE SHEETS
 (In millions, except for share amounts)
 (Unaudited)
 
 June 30,
2009


December 31,
2008ASSETSCurrent assetsCash and cash equivalents

$
—


$
—Accounts and notes receivableCustomer, net of allowance of $2 in 2009 and 2008


59



66Affiliates


6



6Other


3



6Materials and supplies


43



43Deferred income taxes


19



12Prepaids


8



15Other


8



8Total current assets


146



156Property, plant and equipment, at cost


3,842



3,804Less accumulated depreciation and amortization


1,383



1,365Total property, plant and equipment, net


2,459



2,439Other assetsNotes receivable from affiliate


1,128



986Other


102



1031,230



1,089Total assets

$
3,835


$
3,684LIABILITIES AND STOCKHOLDER’S EQUITYCurrent liabilitiesAccounts payableTrade

$
57


$
48Affiliates


21



21Other


13



18Taxes payable


136



79Accrued interest


20



20Accrued liabilities


42



9Regulatory liabilities


26



33Other


26



31Total current liabilities


341



259Long-term debt


1,167



1,166Other liabilitiesDeferred income taxes


396



389Other


63



72459



461Commitments and contingencies (Note 3)Stockholder’s equityCommon stock, par value $1 per share; 1,000 shares authorized, issued and outstanding


—



—Additional paid-in capital


1,268



1,268Retained earnings


600



530Total stockholder’s equity


1,868



1,798Total liabilities and stockholder’s equity

$
3,835


$
3,684
 
 See accompanying notes.
 
 2
 Table of Contents
 
 EL PASO NATURAL GAS COMPANY
 
 CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
 (In millions)
 (Unaudited)
 
 Six Months Ended
June 30,2009


2008Cash flows from operating activitiesNet income

$
70


$
73Adjustments to reconcile net income to net cash from operating activitiesDepreciation and amortization


42



41Deferred income taxes


—



12Other non-cash income items


(3
)


22Asset and liability changes


85



(6
)Net cash provided by operating activities


194



142Cash flows from investing activitiesAdditions to property, plant and equipment


(65
)


(88
)Net change in note receivable from affiliate


(142
)


96Proceeds from disposal of property


14



—Other


(1
)


—Net cash provided by (used in) investing activities


(194
)


8Cash flows from financing activitiesDividend paid to parent


—



(150
)Net cash used in financing activities


—



(150
)Net change in cash and cash equivalents


—



—Cash and cash equivalentsBeginning of period


—



—End of period

$
—


$
—
 
 See accompanying notes.
 
 
 3
 Table of Contents
 
 EL PASO NATURAL GAS COMPANY
 
 NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
 (Unaudited)
 
 1. Basis of Presentation and Significant Accounting Policies
 
 Basis of Presentation
 
 We are an indirect wholly owned subsidiary of El Paso Corporation (El Paso). We prepared this Quarterly Report on Form 10-Q under the rules and regulations of the United States Securities and Exchange Commission (SEC). Because this is an interim period filing presented using a condensed format, it does not include all of
the disclosures required by U.S. generally accepted accounting principles. You should read this Quarterly Report on Form 10-Q along with our 2008 Annual Report on Form 10-K, which contains a summary of our significant accounting policies and other disclosures. The financial statements as of June 30, 2009, and for the quarters and six months ended June 30, 2009 and 2008, are unaudited. We derived the condensed consolidated balance sheet as of December 31, 2008, from the audited balance
sheet filed in our 2008 Annual Report on Form 10-K. In our opinion, we have made all adjustments, which are of a normal recurring nature, to fairly present our interim period results. We have evaluated subsequent events through the time of filing on August 7, 2009, the date of issuance of our financial statements.  Due to the seasonal nature of our business, information for interim periods may not be indicative of our operating results for the entire year.
 
 Significant Accounting Policies
 
 The information below provides an update of our significant accounting policies and accounting pronouncements as discussed in our 2008 Annual Report on Form 10-K.
 
 Fair Value Measurements.On January 1, 2009, we adopted the provisions of Statement of Financial Accounting Standards (SFAS) No. 157, Fair Value Measurements, for our non-financial assets and liabilities that are measured at fair value
on a non-recurring basis, which primarily relates to any impairment of long-lived assets or investments. During the six months ended June 30, 2009, there were no fair value measurements recorded on a non-recurring basis.
 
 Business Combinations and Noncontrolling Interests.On January 1, 2009, we adopted SFAS No. 141(R), Business Combinations, and SFAS No. 160, Noncontrolling Interests in Consolidated Financial
Statements, which provide revised guidance on accounting and reporting for acquisitions of businesses and transactions involving noncontrolling interests. SFAS No. 141(R) changes the current guidance to require that all acquired assets, liabilities, noncontrolling interests and certain contingencies be measured at fair value, and certain other acquisition-related costs be expensed rather than capitalized. SFAS No. 160 requires that all transactions with noncontrolling interest holders, including the issuance
and repurchase of noncontrolling interests, be accounted for as equity transactions unless a change in control of the subsidiary occurs. The adoption of these standards did not have an impact on our financial statements. Application of these standards impacts transactions that are entered into after December 31, 2008.
 
 
 
 4
 Table of Contents
 
 2. Fair Value of Financial Instruments
 
 At June 30, 2009 and December 31, 2008, the carrying amounts of trade and other receivables and payables are representative of their fair value because of the short-term nature of these instruments. At June 30, 2009 and December 31, 2008, we had a note receivable from El Paso of approximately $1.1 billion and $1.0 billion due upon demand, with a
variable interest rate of 1.6% and 3.2%. While we are exposed to changes in interest income based on changes to the variable interest rate, the fair value of this note receivable approximates its carrying value due to the note being due on demand and the market-based nature of its interest rate.
 
 In addition, the carrying amounts and estimated fair values of our long-term debt are based on quoted market prices for the same or similar issues and are as follows:
 
 June 30, 2009


December 31, 2008Carrying
Amount


Fair
Value


Carrying
Amount


Fair
Value(In millions)Long-term debt

$
1,167


$
1,197


$
1,166


$
1,021
 
 3. Commitments and Contingencies
 
 Legal Proceedings
 
 Sierra Pacific Resources and Nevada Power Company v. El Paso et al.In April 2003, Sierra Pacific Resources and Nevada Power Company filed a suit in the U.S. District Court for the District of Nevada against
us, our affiliates and unrelated third parties, alleging that the defendants conspired to manipulate prices and supplies of natural gas in the California-Arizona border market from 1996 to 2001. This matter was settled in June 2009 and the case was dismissed.
  Baldonado et al. v. EPNG.In August 2000, a main transmission line owned and operated by us ruptured at the crossing of the Pecos River near Carlsbad, New Mexico. Individuals at the site were fatally injured.
In June 2003, a lawsuit entitled Baldonado et al. v. EPNGwas filed in state court in Eddy County, New Mexico, on behalf of 26 firemen and emergency medical service personnel who responded to the fire and who allegedly have suffered psychological trauma. The case has been set for trial in September 2009 and discovery is ongoing. Our costs and legal exposure related to this lawsuit are currently not determinable;
however, we believe this matter will be fully covered by insurance.
  Gas Measurement Cases.We and a number of our affiliates were named defendants in actions that generally allege mismeasurement of natural gas volumes and/or heating content resulting in the underpayment
of royalties. The first set of cases was filed in 1997 by an individual under the False Claims Act and have been consolidated for pretrial purposes (In re: Natural Gas Royalties Qui Tam Litigation,U.S. District Court for the District of Wyoming). These complaints allege an industry-wide conspiracy to underreport the heating
value as well as the volumes of the natural gas produced from federal and Native American lands. In October 2006, the U.S. District Judge issued an order dismissing all claims against all defendants. In March 2009, the Tenth Circuit Court of Appeals affirmed the dismissals and in May 2009, the plaintiff’s motion for reconsideration was denied.
  Similar allegations were filed in a second set of actions initiated in 1999 in Will Price, et al. v. Gas Pipelines and Their Predecessors, et al.,in the District Court of Stevens County, Kansas. The plaintiffs currently seek certification of a class of
royalty owners in wells on non-federal and non-Native American lands in Kansas, Wyoming and Colorado. Motions for class certification have been briefed and argued in the proceedings and the parties are awaiting the court’s ruling. The plaintiffs seek an unspecified amount of monetary damages in the form of additional royalty payments (along with interest, expenses and punitive damages) and injunctive relief with regard to future gas measurement practices. Our costs and legal exposure related to these lawsuits
and claims are not currently determinable.
 
 
 5
 Table of Contents
 
 Bank of America.We are a named defendant, along with Burlington Resources, Inc. (Burlington), now a subsidiary of ConocoPhillips, in a class action lawsuit styled Bank of America, et al. v. El Paso Natural Gas and Burlington
Resources Oil and Gas Company, L.P.,filed in October 2003 in the District Court of Kiowa County, Oklahoma asserting royalty underpayment claims related to specified shallow wells in Oklahoma, Texas and New Mexico. The Plaintiffs assert that royalties were underpaid starting in the 1980s when the purchase price of gas was lowered below the Natural Gas Policy Act maximum lawful prices. The Plaintiffs assert that royalties were further underpaid by Burlington as a result of post-production cost deductions
taken starting in the late 1990s. This action was transferred to Washita County District Court in 2004. A tentative settlement reached in November 2005 was disapproved by the court in June 2007. A class certification hearing occurred in April 2009 and we are awaiting a decision by the Court. A companion case styled Bank of America v. El Paso Natural Gasinvolving similar claims made as to certain wells in Oklahoma was settled in 2006. Our costs and legal
exposure related to this lawsuit are not currently determinable.
 
 In addition to the above proceedings, we and our subsidiaries and affiliates are named defendants in numerous lawsuits and governmental proceedings that arise in the ordinary course of our business. For each of these matters, we evaluate the merits of the case, our exposure to the matter, possible legal or settlement strategies and the likelihood
of an unfavorable outcome. If we determine that an unfavorable outcome is probable and can be estimated, we establish the necessary accruals. While the outcome of these matters, including those discussed above, cannot be predicted with certainty, and there are still uncertainties related to the costs we may incur, based upon our evaluation and experience to date, we believe we have established appropriate reserves for these matters. It is possible, however, that new information or future developments could require
us to reassess our potential exposure related to these matters and adjust our accruals accordingly, and these adjustments could be material. At June 30, 2009, we had accrued less than $1 million for our outstanding legal matters.
 
 Environmental Matters
 
 We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remedy the effect on the environment of the disposal or release of specified substances at current and former operating sites. At June 30, 2009 and December 31, 2008, we had
accrued approximately $19 million and $ 22 million for expected remediation costs and associated onsite, offsite and groundwater technical studies and for related environmental legal costs; however, we estimate that our exposure could be as high as $39 million at June 30, 2009. Our accrual at June 30, 2009 includes $17 million for environmental contingencies related to properties we previously owned.
 
 Our accrual represents a combination of two estimation methodologies. First, where the most likely outcome can be reasonably estimated, that cost has been accrued. Second, where the most likely outcome cannot be estimated, a range of costs is established and if no one amount in that range is more likely than any other, the lower end of the expected
range has been accrued. Our environmental remediation projects are in various stages of completion. Our recorded liabilities reflect our current estimates of amounts we will expend to remediate these sites. However, depending on the stage of completion or assessment, the ultimate extent of contamination or remediation required may not be known. As additional assessments occur or remediation efforts continue, we may incur additional liabilities.
 
 For the remainder of 2009, we estimate that our total remediation expenditures will be approximately $4 million, which will be expended under government directed clean-up programs.
 
 
 
 
 6
 Table of Contents
 
 Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) Matters.We have received notice that we could be designated, or have been asked for information to determine whether we could be designated, as a Potentially
Responsible Party (PRP) with respect to three active sites under the CERCLA or state equivalents. We have sought to resolve our liability as a PRP at these sites through indemnification by third parties and settlements which provide for payment of our allocable share of remediation costs. As of June 30, 2009, we have estimated our share of the remediation costs at these sites to be between $8 million and $13 million. Because the clean-up costs are estimates and are subject to revision as more information becomes
available about the extent of remediation required, and in some cases we have asserted a defense to any liability, our estimates could change. Moreover, liability under the federal CERCLA statute is joint and several, meaning that we could be required to pay in excess of our pro rata share of remediation costs. Our understanding of the financial strength of other PRPs has been considered, where appropriate, in estimating our liabilities. Accruals for these matters are included in the environmental reserve discussed
above.
 
 It is possible that new information or future developments could require us to reassess our potential exposure related to environmental matters. We may incur significant costs and liabilities in order to comply with existing environmental laws and regulations. It is also possible that other developments, such as increasingly strict environmental
laws, regulations and orders of regulatory agencies, as well as claims for damages to property and the environment or injuries to employees and other persons resulting from our current or past operations, could result in substantial costs and liabilities in the future. As this information becomes available, or other relevant developments occur, we will adjust our accrual amounts accordingly. While there are still uncertainties related to the ultimate costs we may incur, based upon our evaluation and experience
to date, we believe our reserves are adequate.
 
 Rates and Regulatory Matter
 
 EPNG Rate Case.In June 2008, we filed a rate case with the Federal Energy Regulatory Commission (FERC) as required under the settlement of our previous rate case. The filing proposed an increase in our base tariff rates. In August 2008, the FERC issued an order accepting the proposed rates
effective January 1, 2009, subject to refund and the outcome of a hearing and a technical conference. The FERC issued an order in December 2008 that generally accepted most of our proposals in the technical conference proceeding. The FERC has appointed an administrative law judge to preside over a hearing if we are unable to reach a negotiated settlement with our customers on the remaining issues. The hearing is currently scheduled to begin in late October 2009.  The outcome of the hearing is not currently
determinable.
 
 Other Matters
 
 Navajo Nation.In March 2009, representatives of the Navajo Nation and EPNG executed a final agreement setting forth the full terms and conditions of the Navajo Nation’s consent to EPNG’s rights-of-way through the Navajo Nation.  We submitted the Navajo Nation’s
consent agreement in support of EPNG’s pending application to the United States Department of the Interior (the Department) for an extension of the Department’s current right-of-way grant.  We expect the submission will result in the Department’s final processing of our application. We have filed with the FERC for recovery of these amounts in our recent rate case.
 
 
 7
 Table of Contents
 
 Tuba City Uranium Milling Facility. For a period of approximately ten years beginning in the mid to late 1950s, Rare Metals Corporation of America, a historical affiliate, conducted uranium mining and milling
operations in the vicinity of Tuba City, Arizona, under a contract with the United States government as part of the Cold War nuclear program. The site of the Tuba City uranium mill, which is on land within the Navajo Indian Reservation, reverted to the Navajo Nation after the mill closed in 1966. The tailings at the mill site were encapsulated and a ground water remediation system was installed by the U.S. Department of Energy (DOE) under the Federal Uranium Mill Tailings Radiation Control Act of 1978. In May
2007, we filed suit against the DOE and other federal agencies requesting a judicial determination that the DOE was fully and legally responsible for any remediation of any waste associated with historical uranium production activity at two sites in the vicinity of the mill facilities near Tuba City, Arizona. In March 2009, the United States District Court for the District of Columbia issued an opinion dismissing one of our claims, for which we intend to make an appeal.  Also in March, following our
close cooperation with the Navajo Nation in joint legislative efforts, President Obama signed the Fiscal Year 2009 Omnibus Appropriations Act, which appropriated $5 million toward the final remediation by the DOE of one of the two sites that are the subject of our lawsuit. Pending the remedial response by the United States government, we have taken certain interim site control measures in coordination with the Navajo Nation.
  While the outcome of these matters cannot be predicted with certainty, based on current information, we do not expect the ultimate resolution of these matters to have a material adverse effect on our financial position, operating results or cash flows. It is possible that new information or future developments could require us to reassess our potential
exposure related to these matters. The impact of these changes may have a material effect on our results of operations, our financial position, and our cash flows in the periods these events occur.
 
 Guarantees
  We are or have been involved in various ownership and other contractual arrangements that sometimes require us to provide additional financial support that results in the issuance of financial and performance guarantees that are not recorded in our financial statements. As of June 30, 2009, we have financial and performance guarantees with
a maximum exposure of approximately $11 million.
 
 
 8
 Table of Contents
 
 4. Transactions with Affiliates
 
 Cash Management Program.  We participate in El Paso’s cash management program which matches short-term cash surpluses and needs of participating affiliates, thus minimizing total borrowings from outside sources.  El Paso uses the cash management program to settle
intercompany transactions between participating affiliates. We have historically advanced cash to El Paso in exchange for an affiliated note receivable that is due upon demand. During the first quarter of 2008, we utilized $150 million of our note receivable from the cash management program to pay a dividend to our parent. At June 30, 2009 and December 31, 2008, we had a note receivable from El Paso of approximately $1.1 billion and $1.0 billion. We have classified these amounts as non-current
on our balance sheets as we do not anticipate using them in the next twelve months considering available cash sources and needs. The interest rate on this variable rate note was 1.6% at June 30, 2009 and 3.2% at December 31, 2008.
 
 Income Taxes.  El Paso files consolidated U.S. federal and certain state tax returns which include our taxable income. In certain states, we file and pay taxes directly to the state taxing authorities. At June 30, 2009 and December 31, 2008, we had federal and
state income taxes payable of $121 million and $79 million. The majority of these balances, as well as our deferred income taxes, will become payable to El Paso.
 
 Other Affiliate Balances.  At June 30, 2009 and December 31, 2008, we had contractual deposits from our affiliates of $8 million, included in other current liabilities on our balance sheets.
 
 Affiliate Revenues and Expenses. We enter into transactions with our affiliates within the ordinary course of business. For a further discussion of our affiliated transactions, see our 2008 Annual Report on Form 10-K. The following table shows revenues and charges from our affiliates for
the periods ended June 30:
 
 Quarter Ended
June 30,


Six Months Ended
June 30,2009


2008


2009


2008(In millions)Revenues from affiliates

$
5


$
4


$
10


$
8Operation and maintenance expenses from affiliates


16



14



31



28Reimbursement of operating expenses charged to affiliates


5



5



11



10
 
 9
 Table of Contents
 
 Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
 The information required by this Item is presented in a reduced disclosure format pursuant to General Instruction H to Form 10-Q. In addition, this Item updates, and should be read in conjunction with the information disclosed in our 2008 Annual Report on Form 10-K, and our condensed consolidated financial statements and the accompanying
footnotes presented in Item 1 of this Quarterly Report on Form 10-Q.
 
 Results of Operations
 
 Our management uses earnings before interest expense and income taxes (EBIT) as a measure to assess the operating results and effectiveness of our business. We believe EBIT is useful to investors because it allows them to evaluate more effectively our operating performance using the same performance measure analyzed internally by our management.
We define EBIT as net income adjusted for (i) income taxes, (ii) interest and debt expense, and (iii) affiliated interest income. We exclude interest and debt expense from this measure so that investors may evaluate our operating results without regard to our financing methods. EBIT may not be comparable to measurements used by other companies. Additionally, EBIT should be considered in conjunction with net income and other performance measures such as operating income or operating cash flows. Below is a reconciliation
of our EBIT to net income, our throughput volumes and an analysis and discussion of our results for the six months ended June 30, 2009 compared to the same period in 2008.
 
 Operating Results:

2009


2008(In millions,
except for volumes)Operating revenues

$
301


$
293Operating expenses


(153
)


(159
)Operating income


148



134Other income, net


1



3EBIT


149



137Interest and debt expense


(46
)


(45
)Affiliated interest income, net


10



26Income taxes


(43
)


(45
)Net income

$
70


$
73Throughput volumes (BBtu/d)(1)


3,942



4,231
 ____________
 (1)Throughput volumes exclude throughput transported by the Mojave Pipeline Company (Mojave) system on behalf of EPNG.
 
 EBIT Analysis:

Revenue


Expense


Other


EBIT
ImpactFavorable/(Unfavorable)(In millions)Reservation and other services revenues

$
15


$
—


$
—


$
15Enron bankruptcy settlement


(6
)


(2
)


—



(8
)Operating and general and administrative expenses


—



5



—



5Other (1)


(1
)


3



(2
)


—Total impact on EBIT

$
8


$
6


$
(2
)

$
12
 __________________
 
 (1)Consists of individually insignificant items.
 
 
 10
 Table of Contents
 
 Reservation and Other Services Revenues.Reservation and other services revenues were higher for the six months ended June 30, 2009 compared to 2008, primarily due to an increase of $20 million in reservation charges
for capacity on our EPNG system during the first six months of 2009 primarily resulting from higher contracted capacity to primary delivery points in California and an increase in EPNG’s tariff rates effective January 1, 2009, subject to refund.  Partially offsetting the increase was a $5 million decrease in usage revenues primarily due to reduced throughput in 2009.
 
 We may or may not be able to sustain higher levels of contracted capacity by our customers in the future.  For instance, during the second quarter of 2009, we received notice from one of our major customers that it will not be re-contracting approximately 74 MDth/day of capacity, effective September 1, 2009.  To the extent that
we are unable to re-market this capacity, we estimate our revenues will be adversely affected by approximately $7 million annually based on currently billed rates.  Additionally, although a reduction in throughput on our system is not material to our short-term financial results due to a substantial portion of our revenues being based on firm reservation charges under long-term contracts, it can be an indication of the risks we may face when seeking to re-contract or renew any of our existing firm transportation
contracts.
 
 For the six months ended June 30, 2009, our throughput volumes decreased compared with the same period in 2008. The reduction in throughput was due, in part, to a decrease in natural gas and electric generation demand due to weak macroeconomic conditions in the southwestern U.S. as well as the introduction in April 2009 of a new interstate
natural gas pipeline with approximately 500 MDth/d of capacity serving the greater Phoenix, Arizona area.  We anticipate these factors will continue to negatively affect our throughput.  If these macroeconomic conditions continue, it could negatively impact basis differentials over the longer term and our ability to renew firm transportation contracts that are expiring on our system or our ability to renew such contracts at current rates.  If, however, we determine there is a significant
change in our cost of providing service or billing determinants, we have the option to file a future rate case with the FERC to recover our prudently incurred costs.
 
 In June 2008, we filed a rate case with the FERC as required under the settlement of our previous rate case. The filing proposed an increase in our base tariff rates. In August 2008, the FERC issued an order accepting the proposed rates effective January 1, 2009, subject to refund and the outcome of a hearing and a technical conference. In December
2008, the FERC issued an order that generally accepted most of our proposals in the technical conference proceeding. The FERC appointed an administrative law judge to preside over a hearing if we are unable to reach a negotiated settlement with our customers on the remaining issues. The hearing is currently scheduled to begin in late October 2009.  The outcome of the hearing is not currently determinable.
 
 Enron Bankruptcy Settlement.During the six months ended June 30, 2008, we recorded income of approximately $8 million as a result of settlements received from the Enron bankruptcy.
 
 Operating and General and Administrative Expenses. During the six months ended June 30, 2009, our operating and general and administrative expenses decreased primarily as a result of decreased repair and maintenance.
 
 Affiliated Interest Income, Net
 
 Affiliated interest income, net for the six months ended June 30, 2009, was $16 million lower than the same period in 2008 primarily due to lower average short-term interest rates on advances to El Paso under its cash management program.  The following table shows the average advances due from El Paso and the average short-term interest
rates for the six months ended June 30:
 
 2009


2008(In billions, except for rates)Average advance due from El Paso

$
1.1


$
1.1Average short-term interest rate


2.0
%


4.8
%
 
 Income Taxes
 
 Our effective tax rate of 38 percent for the six months ended June 30, 2009 and 2008 was higher than the statutory rate of 35 percent primarily due to the effect of state income taxes.
 
 11
 Table of Contents
 
 
 Liquidity and Capital Resources
 
 Our primary sources of liquidity are cash flows from operating activities and El Paso’s cash management program. At June 30, 2009, we had a note receivable from El Paso of approximately $1.1 billion. We do not intend to settle this note within the next twelve months and therefore, classified it as non-current on our balance
sheet. See Item 1, Financial Statements, Note 4, for a further discussion of El Paso’s cash management program. Our primary uses of cash are for working capital and capital expenditures.  Our cash capital expenditures for the six months ended June 30, 2009, and our estimated capital expenditures for the remainder of this year to expand and maintain our systems are listed below.
 
 Six Months Ended
June 30, 2009


2009
Remaining


Total(In millions)Maintenance

$
61


$
56


$
117Expansion


4



—



4$
65


$
56


$
121
 
 Extreme volatility in the financial markets, the energy industry and the global economy will likely continue through the remainder of 2009 and possibly beyond, and it is uncertain whether U.S. and foreign government actions will successfully restore confidence and liquidity in the global financial markets. This could impact our longer-term access
to capital for future growth projects as well as the cost of such capital. Additionally, although the impacts are difficult to quantify at this point, a continued downward trend in the global economy could have adverse impacts on natural gas consumption and demand. However, we believe our exposure to changes in natural gas consumption and demand is largely mitigated by a revenue base that is significantly comprised of long-term contracts that are based on firm demand charges and are less affected by a potential
reduction in the actual usage or consumption of natural gas, however we may or may not be able to sustain higher levels of contracted capacity by our customers in the future as further discussed in Results of Operations.
 
 We believe we have adequate liquidity available to us to meet our capital requirements and our existing operating needs through cash flows from operating activities and amounts available to us under El Paso’s cash management program.  As of June 30, 2009, El Paso had approximately $2.3 billion of available liquidity, including $1.5
billion of capacity available to it under various committed credit facilities. In addition to the cash management program above, we are eligible to borrow amounts available under El Paso’s $1.5 billion credit agreement and are only liable for amounts we directly borrow. As of June 30, 2009, El Paso had approximately $0.9 billion of capacity remaining and available to us under this credit agreement, and none of the amount outstanding under the facility was issued or borrowed by us. For a further
discussion of this credit agreement, see our 2008 Annual Report on Form 10-K.  While we do not anticipate a need to directly access the financial markets in the remainder of 2009 for any of our operating activities or expansion capital needs based on liquidity available to us, volatility in the financial markets could impact our or El Paso’s ability to access these markets at reasonable rates in the future.
 
 
 
 12
 Table of Contents
 
 Commitments and Contingencies
 
 For a further discussion of our commitments and contingencies, see Item 1, Financial Statements, Note 3, which is incorporated herein by reference.
 
 Climate Change and Energy Legislation.There are various legislative and regulatory measures relating to climate change and energy policies that have been proposed that, if enacted, will likely impact our business.
 
 Climate Change Regulation.Measures to address climate change and greenhouse gas (GHG) emissions are in various phases of discussions or implementation at international, federal, regional and state levels. It is likely that federal legislation requiring GHG controls will be
enacted in the next few years in the United States.  Although it is uncertain what legislation will ultimately be enacted, it is our belief that cap-and-trade or other legislation that sets a price on carbon emissions will increase demand for natural gas, particularly in the power sector.  We believe this increased demand will occur due to substantially less carbon emissions associated with the use of natural gas compared with alternate fuel sources for power generation, including coal and
oil-fired power generation.  However, the actual impact on demand will depend on the legislative provisions that are ultimately adopted, including the level of emission caps, allowances granted and the cost of emission credits.
 
 It is also likely that any federal legislation that is enacted would increase our cost of environmental compliance by requiring us to install additional equipment to reduce carbon emissions from our larger facilities as well as to potentially purchase emission credits.  Based on 2007 data we reported to the California Climate Action Registry
(CCAR), our operations in the United States emitted approximately 3.5 million tonnes of carbon dioxide equivalent emissions in 2007. We believe that approximately 2.9 million tonnes of the GHG emissions that we reported to CCAR would be subject to regulation under the climate change legislation that passed in the U.S. House of Representatives in July 2009, with approximately 57 percent of this amount being subject to the cap-and-trade rules contained in the proposed legislation and the remainder being subject
to performance standards.  As proposed, the portion of our GHG emissions that would be subject to performance standards could require us to install additional equipment or initiate new work practice standards to reduce emission levels at many of our facilities, the costs of which would likely be material.  Although we believe that many of these costs should be recoverable in the rates charged to our customers, recovery is still uncertain at this time.
  The Environmental Protection Agency (EPA) is also considering new regulations to regulate GHGs under the Clean Air Act, as well as to monitor and report GHG emissions on an annual basis.  In addition, various lawsuits have been filed seeking to force further regulation of GHG emissions, as well as to require specific companies to reduce
GHG emissions from their operations. Enactment of additional regulations, as well as lawsuits, could have an impact on our ability to obtain permits and other regulatory approvals with regard to existing and new facilities, could impact our costs of operations, as well as require us to install new equipment to control emissions from our facilities.
  Energy Legislation.In conjunction with these climate change proposals, there have been various federal and state legislative and regulatory proposals that would create additional incentives to move to a less carbon intensive “footprint”.  These proposals
establish renewable portfolio standards at both the federal and state level, some of which would require a material increase of renewable sources, such as wind and solar power generation, over the next several decades.  Additionally, the proposals establish incentives for energy efficiency and conservation.  Although the ultimate targets that are established in these areas are uncertain at this time, such proposals if enacted could negatively
impact natural gas usage over the longer term.
 
 
 13
 Table of Contents
 
 Item 3. Quantitative and Qualitative Disclosures About Market Risk
 
 Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.
 
 Item 4. Controls and Procedures
 
 Evaluation of Disclosure Controls and Procedures
 
 As of June 30, 2009, we carried out an evaluation under the supervision and with the participation of our management, including our President and our Chief Financial Officer, as to the effectiveness, design and operation of our disclosure controls and procedures. This evaluation considered the various processes carried out under the direction of
our disclosure committee in an effort to ensure that information required to be disclosed in the SEC reports we file or submit under the Exchange Act is accurate, complete and timely. Our management, including our President and Chief Financial Officer, does not expect that our disclosure controls and procedures or our internal controls will prevent and/or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the
objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within our company have been detected. Our disclosure controls and procedures are designed to provide reasonable assurance of achieving
their objective and our President and Chief Financial Officer have concluded that our disclosure controls and procedures are effective at a reasonable level of assurance at June 30, 2009.
 
 Changes in Internal Control Over Financial Reporting
 
 There were no changes in our internal control over financial reporting during the second quarter of 2009 that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.
 
 
 14
 Table of Contents
 
 PART II — OTHER INFORMATION
 
 Item 1. Legal Proceedings
 
 See Part I, Item 1, Financial Statements, Note 3, which is incorporated herein by reference.
 
 Item 1A. Risk Factors
 
 CAUTIONARY STATEMENTS FOR PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF
 THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
 
 This report contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements are based on assumptions or beliefs that we believe to be reasonable; however, assumed facts almost always vary from actual results, and differences between assumed facts and actual results
can be material, depending upon the circumstances. Where, based on assumptions, 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 stated expectation or belief will occur, be achieved or accomplished. The words “believe,” “expect,” “estimate,” “anticipate,” and similar expressions will generally identify
forward-looking statements. All of our forward-looking statements, whether written or oral, are expressly qualified by these cautionary statements and any other cautionary statements that may accompany such forward-looking statements. In addition, we disclaim any obligation to update any forward-looking statements to reflect events or circumstances after the date of this report.
 
 Important factors that could cause actual results to differ materially from estimates or projections contained in forward-looking statements are described in our 2008 Annual Report on Form 10-K under Part I, Item 1A, Risk Factors. There have been no material changes in these risk factors since that report.
 
 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
 
 Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.
 
 Item 3. Defaults Upon Senior Securities
 
 Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.
 
 Item 4. Submission of Matters to a Vote of Security Holders
 
 Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.
 
 Item 5. Other Information
 
 None.
 
 
 15
 Table of Contents
 
 Item 6. Exhibits
 
 The Exhibit Index is hereby incorporated herein by reference and sets forth a list of those exhibits filed herewith.
 
 The agreements included as exhibits to this report are intended to provide information regarding their terms and not to provide any other factual or disclosure information about us or the other parties to the agreements. The agreements may contain representations and warranties by the parties to the agreements, including us, solely for the benefit
of the other parties to the applicable agreement and:
 
 ·
should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate;
 ·
may have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement, which disclosures are not necessarily reflected in the agreement;
 ·
may apply standards of materiality in a way that is different from what may be viewed as material to certain investors; and
 ·
were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement and are subject to more recent developments.
 
 Accordingly, these representations and warranties may not describe the actual state of affairs as of the date they were made or at any other time.
 
 
 16
 Table of Contents
 
 SIGNATURES
 
 Pursuant to the requirements of the Securities Exchange Act of 1934, El Paso Natural Gas Company has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 EL PASO NATURAL GAS COMPANYDate:  August 7, 2009
/s/ James J. ClearyJames J. ClearyPresident(Principal Executive Officer)Date:  August 7, 2009
/s/ John R. SultJohn R. SultSenior Vice President,Chief Financial Officer and Controller(Principal Accounting and Financial Officer)
      
 17
 Table of Contents
 
 EL PASO NATURAL GAS COMPANY
 
 EXHIBIT INDEX
 
 Each exhibit identified below is filed as a part of this report.
 
 Exhibit
Number
Description12
Ratio of Earnings to Fixed Charges.31.A
Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.31.B
Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.32.A
Certification of Principal Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.32.B
Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.






















18