UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2012

¨	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 1-2700

El Paso Natural Gas Company

(Exact Name of Registrant as Specified in Its Charter)


Delaware		74-0608280
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

El Paso Building
1001 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 x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, 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 x 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	x (Do not check if a smaller reporting company)	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 x

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 May 2, 2012: 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	Page
	PART I — Financial Information
Item 1.	Financial Statements		1
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		10
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		*
Item 4.	Controls and Procedures		13
	PART II — Other Information
Item 1.	Legal Proceedings		14
Item 1A.	Risk Factors		14
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		*
Item 3.	Defaults Upon Senior Securities		*
Item 4.	Mine Safety Disclosures		14
Item 5.	Other Information		14
Item 6.	Exhibits		15
	Signatures		16

*	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		BBtu = billion British thermal units

When we refer to “us,” “we,” “our” or “ours,” we are describing El Paso Natural Gas Company and/or our subsidiaries.

PART I — FINANCIAL INFORMATION

Item 1. Financial Statements

EL PASO NATURAL GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(In millions)

(Unaudited)


	Quarter Ended March 31,
	2012			2011
Operating revenues	$	131		$	124

Operating expenses
Operation and maintenance		53			46
Depreciation and amortization		23			23
Taxes, other than income taxes		8			8

		84			77

Operating income		47			47
Other income		1			1
Interest and debt expense		(22	)		(22	)
Affiliated interest income, net		5			3

Income before income taxes		31			29
Income tax expense		12			11

Net income		19			18
Other comprehensive income
Unrealized actuarial gains on postretirement benefit obligations		—			—

Comprehensive income	$	19		$	18

See accompanying notes.

EL PASO NATURAL GAS COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions, except share amounts)

(Unaudited)


	March 31, 2012		December 31, 2011
ASSETS
Current assets
Cash and cash equivalents	$	6	$	—
Accounts and note receivable
Customer, net of allowance		10		3
Affiliates		2		3
Other		21		24
Materials and supplies		49		48
Deferred income taxes		12		12
Prepaids		11		16
Regulatory assets		8		8
Other		1		—

Total current assets		120		114

Property, plant and equipment, at cost		3,971		3,993
Less accumulated depreciation and amortization		1,535		1,525

Total property, plant and equipment, net		2,436		2,468

Other long-term assets
Note receivable from affiliate		878		873
Other		101		101

		979		974

Total assets	$	3,535	$	3,556


LIABILITIES AND STOCKHOLDER’S EQUITY
Current liabilities
Accounts payable
Trade	$	63	$	68
Affiliates		15		20
Other		11		9
Taxes payable		32		35
Accrued interest		29		19
Accrued liabilities		30		29
Regulatory liabilities		14		16
Contractual deposits		21		21
Other		6		6

Total current liabilities		221		223

Long-term debt		1,113		1,113

Other long-term liabilities
Deferred income taxes		449		439
Other		90		78

		539		517

Commitments and contingencies (Note 3)
Stockholder’s equity
Common stock, par value $1 per share; 1,000 shares authorized, issued and outstanding		—		—
Additional paid-in capital		1,268		1,268
Retained earnings		391		432
Accumulated other comprehensive income		3		3

Total stockholder’s equity		1,662		1,703

Total liabilities and stockholder’s equity	$	3,535	$	3,556

See accompanying notes.

EL PASO NATURAL GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)


	Quarter Ended March 31,
	2012			2011
Cash flows from operating activities
Net income	$	19		$	18
Adjustments to reconcile net income to net cash from operating activities
Depreciation and amortization		23			23
Deferred income tax expense		10			1
Other non-cash income items		(2	)		9
Asset and liability changes		33			24

Net cash provided by operating activities		83			75

Cash flows from investing activities
Capital expenditures		(12	)		(23	)
Net change in note receivable from affiliate		(5	)		(31	)

Net cash used in investing activities		(17	)		(54	)

Cash flows from financing activities
Dividends paid to parent		(60	)		(21	)

Net cash used in financing activities		(60	)		(21	)

Net change in cash and cash equivalents		6			—
Cash and cash equivalents
Beginning of period		—			—

End of period	$	6		$	—

See accompanying notes.

EL PASO NATURAL GAS COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Basis of Presentation and Significant Accounting Policies

Basis of Presentation

We prepared this Quarterly Report on Form 10-Q under the rules and regulations of the United States Securities and Exchange Commission. As 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, and should be read along with our 2011 Annual Report on Form 10-K. The financial statements as of March 31, 2012, and for the quarters ended March 31, 2012 and 2011, are unaudited. The condensed consolidated balance sheet as of December 31, 2011, was derived from the audited balance sheet filed in our 2011 Annual Report on Form 10-K. In our opinion, we have made 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 be indicative of our operating results for the entire year. Our disclosures in this Form 10-Q are an update to those provided in our 2011 Annual Report on Form 10-K.

In October 2011, El Paso Corporation (El Paso) entered into a definitive merger agreement with Kinder Morgan, Inc. (KMI) whereby KMI will acquire El Paso in a transaction that valued El Paso at approximately $38 billion (based on the KMI stock price at that date), including the assumption of debt. In March 2012, both El Paso’s and KMI’s stockholders approved the merger agreement and a series of transactions to effectuate the merger. On May 1, 2012, KMI announced that it received approval from the Federal Trade Commission (FTC) for the merger, subject to the previously announced divestiture of certain assets. The completion of the merger transactions is expected by the end of May 2012, subject to other remaining closing conditions and regulatory approvals.

Significant Accounting Policies

There were no changes in the significant accounting policies described in our 2011 Annual Report on Form 10-K and no significant accounting pronouncements issued but not yet adopted as of March 31, 2012.

2. Financial Instruments

The following table reflects the carrying value and fair value of our long-term debt:


	March 31, 2012				December 31, 2011
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)
Long-term debt	$	1,113	$	1,322	$	1,113	$	1,348

We estimated the fair value of our long-term debt (representing a Level 2 fair value measurement further discussed below) primarily based on quoted market prices for the same or similar issuances. As of March 31, 2012 and December 31, 2011, the carrying amounts of cash and cash equivalents, accounts receivable and accounts payable represent fair value based on the short-term nature of these instruments. The carrying amount of our affiliate note receivable approximates its fair value based on an analysis of the nature of the interest rate and our assessment of the ability to recover this amount.

We separate the fair values of our financial instruments into three levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. Our assessment and classification of an instrument within a level can change over time based on the maturity or liquidity of the instrument and would be reflected at the end of the period in which the change occurs. During the quarter ended March 31, 2012, there have been no changes to the inputs and valuation techniques used to measure fair value, the types of instruments, or the levels in which they are classified.

3. Commitments and Contingencies

Legal Proceedings

Bank of America. We are a named defendant, along with Burlington Resources, Inc. (Burlington), now a subsidiary of ConocoPhillips Company, 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 have only alleged an amount of damages against our co-defendant, Burlington. We believe that our actions in the 1980s were proper in light of a declining market. We also contend that we are entitled to an indemnity from Burlington under our 1992 separation agreement for all claims related to royalty payments, which Burlington denies. The Plaintiffs assert that royalties were further underpaid by Burlington as a result of post-production cost deductions taken starting in the late 1990s. We have no liability for the post-production claims as they pertain to periods after our separation from Burlington. This action was transferred to Washita County District Court in 2004. A tentative settlement reached in November 2005 was rejected by the court in June 2007. A class certification hearing occurred in April 2009. The court certified a Texas and Oklahoma class of royalty owners and stayed the claims pertaining to New Mexico wells. The class certification was upheld by the Oklahoma Court of Appeals, and a petition for review was denied by the Oklahoma Supreme Court. The Plaintiffs have proceeded with discovery of the post-production claims against Burlington. The Defendants have filed a motion to dismiss the New Mexico claims because of a pending New Mexico class action covering the same claims. Our costs and legal exposure related to this lawsuit are not currently determinable.

State of Texas v. EPNG. On behalf of the Texas Commission on Environmental Quality, the State of Texas has filed a lawsuit against us related to allegedly unauthorized emissions of air contaminants associated with the rupture of one of our pipelines in the vicinity of Bushland, Texas in 2009. The parties have reached an agreement to settle this matter which is subject to public notice and comment before it can be finalized. The settlement will not have a material adverse effect on our financial condition.

In addition to the above proceeding, we and our affiliates are named defendants in numerous legal proceedings and claims that arise in the ordinary course of our business. For each of these matters, we evaluate the merits of the case or claim, 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 had no accruals for our outstanding legal proceedings at March 31, 2012. It is possible, however, that new information or future developments could require us to reassess our potential exposure related to these matters and establish accruals accordingly.

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 of the disposal or release of specified substances at current and former operating sites. At March 31, 2012, our accrual was approximately $17 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 $27 million. Our accrual includes $16 million for environmental contingencies related to properties we previously owned.

Our environmental remediation projects are in various stages of completion. Our recorded liabilities reflect our current estimates of amounts we will spend 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 2012, we estimate that our total remediation expenditures will be approximately $3 million, most of which will be expended under government directed clean-up plans. In addition, we expect to make capital expenditures for environmental matters of approximately $2 million in the aggregate for the remainder of 2012 through 2016, including capital expenditures associated with the impact of the Environmental Protection Agency (EPA) rule on emissions of hazardous air pollutants from reciprocating internal combustion engines which are subject to regulations with which we have to be in compliance by October 2013.

On April 17, 2012, the EPA issued regulations pursuant to the federal Clean Air Act to reduce various air pollutants from the oil and natural gas industry. These regulations will limit emissions from certain equipment including compressors, storage vessels and natural gas processing plants. We are still evaluating the regulations and their impact on our operations and our financial results.

Superfund Matters. Included in our recorded environmental liabilities are projects where we have received notice that we have been designated or could be designated as a Potentially Responsible Party (PRP) under the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), commonly known as Superfund, or state equivalents for three active sites. Liability under the federal CERCLA statute may be joint and several, meaning that we could be required to pay in excess of our pro rata share of remediation costs. We consider the financial strength of other PRPs in estimating our liabilities. Accruals for these issues 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 Matters

EPNG Rate Cases. In April 2010, the Federal Energy Regulatory Commission (FERC) approved an offer of settlement which increased our base tariff rates, effective January 1, 2009. The settlement resolved all but four issues in the proceeding. In January 2011, the Presiding Administrative Law Judge issued a decision that for the most part found against us on the four issues. We have appealed those decisions to the FERC and may also seek review of any of the FERC’s decisions to the U.S. Court of Appeals. Although the final outcome is not currently determinable, we believe our accruals established for this matter are adequate.

In September 2010, we filed a new rate case with the FERC proposing an increase in base tariff rates which would increase revenues by approximately $100 million annually over previously effective tariff rates. In October 2010, the FERC issued an order accepting and suspending the effective date of the proposed rates to April 1, 2011, subject to refund, the outcome of a hearing and other proceedings. A hearing commenced in late October 2011 and concluded in December 2011. A decision is due in May 2012. It is uncertain whether such an increase will be achieved in the context of any settlement between us and our customers or following the outcome of the hearing in the rate case. Although the final outcome is not currently determinable, we believe our accruals established for this matter are adequate.

Other Regulatory Matters. In October 2010, we filed with the FERC to temporarily idle nine compressor stations along our south mainline system in 2011. This was done to better align our capacity to the current lower level of contract demand resulting from, in part, the weakened economic conditions along this line. Our intent was to bring the idled facilities back into service over the next several years as market demand improves. In our 2010 rate case, we did not initially seek to earn a return on the original investment in the idled facilities. We will continue to incur related operating costs and depreciation expense until the compressor stations are idled. In April 2011, the FERC denied our request to temporarily idle the nine compressor stations. We have appealed the FERC’s decision and the outcome is uncertain.

In January 2012, separately from our October 2010 filing, we filed with the FERC to permanently abandon two compressor stations and four compressor units on our north mainline and San Juan triangle to better align our capacity with current contract demand. Several customers filed protests to our application. We requested an order by December 31, 2012.

Other Matter

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 for the benefit 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, which has been affirmed by the Court of Appeals for the D.C. Circuit. Also in March 2009, 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. The DOE assigned to the Navajo Nation the obligation to perform the final remediation of the site which was completed in August 2011. Additionally, the EPA and Bureau of Indian Affairs (BIA) have entered into an administrative order of consent, pursuant to which the BIA is conducting a remedial investigation/feasibility study at a second site involved in the lawsuit. The remedial investigation/feasibility study is expected to be completed by 2014. Additionally, the United States has filed counterclaims in the District of Columbia alleging that, to the extent we contributed to the disposal of any waste at the second site, we should bear part of the remediation costs at that site. The United States filed a motion to dismiss our remaining claims, which was granted by the district court in March 2012. We will appeal any final judgment. Finally, the EPA is currently assessing the environmental condition of all former uranium mines on the Navajo Indian Reservation to determine the need for further environmental response activities. There are approximately 500 abandoned uranium mine sites on the Navajo Indian Reservation, 16 of which were operated by the historical affiliate. The final outcome of these legal proceedings, remediation and feasibility studies, and environmental assessments is uncertain.

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.

Other Commitments

For further discussion of our other commitments, see our 2011 Annual Report on Form 10-K.

4. Accounts Receivable Sales Program

We currently participate in an accounts receivable sales program where we sell receivables in their entirety to a third party financial institution (through a wholly-owned special purpose entity). The existing program is scheduled to terminate on May 29, 2012 however, we are evaluating options to extend the program. The sale of these accounts receivable (which are short-term assets that generally settle within 60 days) qualify for sale accounting. The third party financial institution involved in our accounts receivable sales program acquires interests in various financial assets and issues commercial paper to fund those acquisitions. We do not consolidate the third party financial institution because we do not have the power to control, direct or exert significant influence over its overall activities since our receivables do not comprise a significant portion of its operations.

In connection with our accounts receivable sales, we receive a portion of the sales proceeds up front and receive an additional amount upon the collection of the underlying receivables (which we refer to as a deferred purchase price). Our ability to recover the deferred purchase price is based solely on the collection of the underlying receivables. The tables below contain information related to our accounts receivable sales program.


	Quarter Ended March 31,
	2012		2011
	(In millions)
Accounts receivable sold to the third party financial institution⁽¹⁾	$	137	$	128
Cash received for accounts receivable sold under the program		80		76
Deferred purchase price related to accounts receivable sold		57		52
Cash received related to the deferred purchase price		57		44

(1)	During the quarters ended March 31, 2012 and 2011, losses recognized on the sale of accounts receivable were immaterial.


	March 31, 2012		December 31, 2011
	(In millions)
Accounts receivable sold and held by third party financial institution	$	46	$	50
Uncollected deferred purchase price related to accounts receivable sold⁽¹⁾		21		21

(1)	Initially recorded at an amount which approximates its fair value using observable inputs other than quoted prices in active markets (Level 2 fair value measurement).

The deferred purchase price related to the accounts receivable sold is reflected as other accounts receivable on our balance sheet. Because the cash received up front and the deferred purchase price relate to the sale or ultimate collection of the underlying receivables, and are not subject to significant other risks given their short term nature, we reflect all cash flows under the accounts receivable sales program as operating cash flows on our statement of cash flows. Under the accounts receivable sales program, we service the underlying receivables for a fee. The fair value of this servicing agreement, as well as the fees earned, were not material to our financial statements for the quarters ended March 31, 2012 and 2011.

5. 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. At March 31, 2012 and December 31, 2011, we had a note receivable from El Paso of $878 million and $873 million. We have classified this receivable as noncurrent on our balance sheet at March 31, 2012 as we do not anticipate using it in the next twelve months considering available cash sources and needs. The interest rate on this note is variable and was 2.5% at March 31, 2012 and December 31, 2011. In the first quarter of 2012, we utilized $60 million of our note receivable from the cash management program to pay a dividend to our parent.

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 March 31, 2012 and December 31, 2011, we had federal and state income taxes payable of $23 million and $21 million. The majority of these balances, as well as our deferred income taxes, will become payable to El Paso.

Other Affiliate Balances. At March 31, 2012 and December 31, 2011, we had contractual deposits from our affiliates of $9 million.

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 2011 Annual Report on Form 10-K. The following table shows revenues, expenses and reimbursements from our affiliates for the quarters ended March 31:


	2012		2011
	(In millions)
Revenues	$	5	$	4
Operation and maintenance expenses		19		18
Reimbursements of operating expenses		2		2

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 2011 Annual Report on Form 10-K, and the financial statements and notes presented in Item 1 of this Quarterly Report on Form 10-Q.

In October 2011, El Paso entered into a definitive merger agreement with KMI whereby KMI will acquire El Paso in a transaction that values El Paso at approximately $38 billion (based on the KMI stock price at that date), including the assumption of debt. In March 2012, both El Paso’s and KMI’s stockholders approved the merger agreement and a series of transactions to effectuate the merger. On May 1, 2012, KMI announced that it received approval from the FTC for the merger, subject to the previously announced divestiture of certain assets. The completion of the merger transactions is expected by the end of May 2012, subject to other remaining closing conditions and regulatory approvals.

In April 2012, KMI announced that, subject to the completion of the merger with El Paso, it expects to drop down a portion of El Paso’s interest in us to Kinder Morgan Energy Partners, L.P., a consolidated subsidiary of KMI, which is expected to occur in the third quarter of 2012.

Results of Operations

Our management uses segment earnings before interest expense and income taxes (Segment EBIT) to measure and assess the operating results and effectiveness of our business. We believe Segment EBIT is useful to our investors because it allows them to use the same performance measure analyzed internally by our management and allows them to evaluate the performance of our business without regard to the manner in which it is financed. Segment EBIT is defined as net income adjusted for items such as (i) interest and debt expense, (ii) affiliated interest income, and (iii) income taxes. Segment EBIT may not be comparable to measurements used by other companies. Additionally, Segment EBIT should be considered in conjunction with net income, income before income taxes and other performance measures such as operating income or operating cash flows. Below is a reconciliation of our Segment EBIT to net income, our throughput volumes and an analysis and discussion of our results for the quarter ended March 31, 2012 compared with the same period in 2011.

Operating Results:


	2012			2011
	(In millions, except for volumes)
Operating revenues	$	131		$	124
Operating expenses		(84	)		(77	)

Operating income		47			47
Other income		1			1

Segment EBIT		48			48
Interest and debt expense		(22	)		(22	)
Affiliated interest income, net		5			3
Income taxes		(12	)		(11	)

Net income	$	19		$	18

Throughput volumes (BBtu/d)⁽¹⁾		3,032			3,054

(1)	Throughput volumes exclude throughput transported by the Mojave system on behalf of EPNG.

Segment EBIT Analysis


	Variance
	Operating Revenue		Operating Expense			Total
	Favorable/(Unfavorable)
	(In millions)
Reservation and usage revenues	$	7	$	—		$	7
Operating and general and administrative expenses		—		(5	)		(5	)
Other⁽¹⁾		—		(2	)		(2	)

Total impact on Segment EBIT	$	7	$	(7	)	$	—

(1)	Consists of individually insignificant items.

Reservation and Usage Revenues. Effective April 1, 2011, our rates, which are subject to refund, increased pursuant to our 2010 rate case resulting in an increase in reservation revenues. Partially offsetting these amounts was slightly lower throughput on our system due to increased competition in the California market. The overall favorable impact of these items to our Segment EBIT for the quarter ended March 31, 2012 compared to 2011 was approximately $7 million.

Operating and General and Administrative Expenses. During the quarter ended March 31, 2012, our operating and general and administrative expenses were higher compared to the same period in 2011 primarily due to higher payroll and contractor costs.

Regulatory Matters

EPNG Rate Cases. We periodically file for changes in our rates, which are subject to approval by the FERC. Changes in rates and other tariff provisions resulting from these regulatory proceedings have the potential to positively or negatively impact our profitability.

•

2010 Rate Case. In September 2010, we filed a new rate case with the FERC proposing an increase in base tariff rates which would increase revenues by approximately $100 million annually over previously effective tariff rates. In October 2010, the FERC issued an order accepting and suspending the effective date of the proposed rates to April 1, 2011, subject to refund, the outcome of a hearing and other proceedings. A hearing commenced in late October 2011 and concluded in December 2011. A decision is due in May 2012. It is uncertain whether such an increase will be achieved in the context of any settlement between us and our customers or following the outcome of the hearing in the rate case. Although the final outcome is not currently determinable, we believe our accruals established for this matter are adequate.

•

2008 Rate Case. In April 2010, the FERC approved an offer of settlement which increased our base tariff rates effective January 1, 2009. The settlement resolved all but four issues in the proceeding. In January 2011, the Presiding Administrative Law Judge issued a decision that for the most part found against us on the four issues. We have appealed those decisions to the FERC and may also seek review of any of the FERC’s decisions to the U.S. Court of Appeals. Although the final outcome is not currently determinable, we believe our accruals established for this matter are adequate.

Although these rate cases are intended to address significant factors leading to the loss in revenues or increased costs, they will not eliminate all ongoing business risks.

Affiliated Interest Income, Net

The following table shows the average advances due from El Paso and the average short-term interest rates for the quarters ended March 31:


	2012			2011
	(In billions, except for rates)
Average advance due from El Paso	$	0.9		$	0.8
Average short-term interest rate		2.5	%		1.5	%

Income Taxes

Our effective tax rates of 39 percent and 38 percent for the quarters ended March 31, 2012 and 2011 were higher than the statutory rate of 35 percent primarily due to the effect of state income taxes.

Liquidity and Capital Resources

Our primary sources of liquidity are cash flows from operating activities and amounts available to us under El Paso’s cash management program while our primary uses of cash are for working capital and capital expenditures. At March 31, 2012, we had a note receivable from El Paso of $878 million. We do not intend to settle any amounts owed under this note within the next twelve months and, therefore, classified it as non-current on our balance sheet. We periodically evaluate our operating cash flows, after consideration of our capital and other requirements, to determine potential discretionary dividends to our parent. Based on our evaluation, during the first quarter of 2012, we paid a dividend to our parent of $60 million. See Item 1. Financial Statements, Note 5, for a further discussion of El Paso’s cash management program.

Our cash capital expenditures for the quarter ended March 31, 2012 are listed below:


	(In millions)
Maintenance	$	11
Expansion		1

	$	12

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. In addition, we are eligible to borrow amounts available under El Paso’s revolving credit agreement and are only liable for amounts we directly borrow. As of March 31, 2012, El Paso had $731 million of capacity remaining and available to us and our affiliates 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 2011 Annual Report on Form 10-K. While we do not anticipate a need to directly access the financial markets for the remainder of 2012 for any of our operating activities or maintenance capital needs based on liquidity available to us, market conditions may impact our or El Paso’s ability to act opportunistically. Our future plans could also be impacted by the completion of El Paso’s announced acquisition by KMI.

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 and our 2011 Annual Report on Form 10-K.

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 March 31, 2012, we carried out an evaluation under the supervision and with the participation of our management, including our President and Chief Financial Officer (CFO), 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 U.S. Securities and Exchange Commission reports we file or submit under the Securities Exchange Act of 1934, as amended (Exchange Act) is accurate, complete and timely. Our management, including our President and CFO, 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 objectives and our President and CFO concluded that our disclosure controls and procedures (as defined in Exchange Act Rules 13a – 15(e) and 15d – 15(e)) were effective as of March 31, 2012.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting during the first quarter of 2012 that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.

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 2011 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. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

The Exhibit Index is incorporated herein by reference.

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.

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 COMPANY

Date: May 4, 2012				/s/ James J. Cleary
				James J. Cleary
				President
				(Principal Executive Officer)


Date: May 4, 2012				/s/ John R. Sult
				John R. Sult
				Executive Vice President and
				Chief Financial Officer
				(Principal Financial Officer)

EL PASO NATURAL GAS COMPANY

EXHIBIT INDEX

Each exhibit identified below is filed as a part of this report.


Exhibit Number		Description

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.

101.INS		XBRL Instance Document.

101.SCH		XBRL Schema Document.

101.CAL		XBRL Calculation Linkbase Document.

101.LAB		XBRL Labels Linkbase Document.

101.PRE		XBRL Presentation Linkbase Document.

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EL PASO NATURAL GAS CO 10-Q