10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2013

or

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

Commission File No. 1-2921

PANHANDLE EASTERN PIPE LINE COMPANY, LP

(Exact name of registrant as specified in its charter)

Delaware	44-0382470
(state or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

3738 Oak Lawn Avenue,

Dallas, Texas 75219

(Address of principle executive offices) (zip code)

(214) 981-0700

(Registrant’s telephone number, including area code)

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 xNo ¨

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes xNo ¨

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   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

Panhandle Eastern Pipe Line Company, LP meets the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format.  Item 2 of Part I has been reduced and Item 3 of Part I and Items 2 and 3 of Part II have been omitted in accordance with Instruction H.

PANHANDLE EASTERN PIPE LINE COMPANY, LP

TABLE OF CONTENTS

		PAGE
PART I - FINANCIAL INFORMATION
ITEM 1.	FINANCIAL STATEMENTS (UNAUDITED)	1
	Condensed Consolidated Balance Sheets	2
	Condensed Consolidated Statements of Operations	4
	Condensed Consolidated Statements of Comprehensive Income (Loss)	5
	Condensed Consolidated Statement of Partners’ Capital	6
	Condensed Consolidated Statements of Cash Flows	7
	Notes to Condensed Consolidated Financial Statements	8
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	14
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	17
ITEM 4.	CONTROLS AND PROCEDURES	17
PART II - OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	17
ITEM 1A.	RISK FACTORS	17
ITEM 6.	EXHIBITS	18
SIGNATURE		19

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Forward-Looking Statements

Certain matters discussed in this report, excluding historical information, as well as some statements by Panhandle Eastern Pipe Line Company, LP and its subsidiaries (“Panhandle” or the “Company”) in periodic press releases and some oral statements of the Company’s officials during presentations about the Company, include forward-looking statements. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. Statements using words such as “anticipate,” “believe,” “intend,” “project,” “plan,” “expect,” “continue,” “estimate,” “goal,” “forecast,” “may,” “will” or similar expressions help identify forward-looking statements. Although the Company believes such forward-looking statements are based on reasonable assumptions and current expectations and projections about future events, no assurance can be given that such assumptions, expectations, or projections will prove to be correct. Forward-looking statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, the Company’s actual results may vary materially from those anticipated, projected, forecasted, estimated or expressed in forward-looking statements since many of the factors that determine these results are subject to uncertainties and risks that are difficult to predict and beyond management’s control. For additional discussion of risks, uncertainties and assumptions, see “Part I — Item 1A. Risk Factors” in the Company's Report on Form 10-K for the year ended December 31, 2012 filed with the Securities and Exchange Commission on March 1, 2013.

Definitions

The following is a list of certain acronyms and terms generally used in the energy industry and throughout this document:

/d	per day
Bcf	Billion cubic feet
Btu	British thermal units
Citrus	Citrus Corp.
EPA	United States Environmental Protection Agency
ETE	Energy Transfer Equity, L.P.
ETP	Energy Transfer Partners, L.P., a subsidiary of ETE
Exchange Act	Securities Exchange Act of 1934
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the United States of America
Holdco	ETP Holdco Corporation
LIBOR	London Interbank Offer Rate
LNG	Liquefied natural gas
LNG Holdings	Trunkline LNG Holdings, LLC
OPEB plans	Other postretirement employee benefit plans
PCBs	Polychlorinated biphenyls
PEPL	Panhandle Eastern Pipe Line Company, LP
PEPL Holdings	PEPL Holdings, LLC
ppb	parts per billion
Sea Robin	Sea Robin Pipeline Company, LLC
SEC	United States Securities and Exchange Commission

ii

Southern Union	Southern Union Company
Sunoco	Sunoco, Inc.
TBtu	Trillion British thermal units
Trunkline	Trunkline Gas Company, LLC
Trunkline LNG	Trunkline LNG Company, LLC

iii

PART 1. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Southern Union’s March 26, 2012 merger transaction with ETE (the “ETE Merger”) was accounted for by ETE using business combination accounting. Under this method, the purchase price paid by the acquirer is allocated to the assets acquired and liabilities assumed as of the acquisition date based on their fair value. By the application of “push-down” accounting, PEPL’s assets, liabilities and partners’ capital were accordingly adjusted to fair value on March 26, 2012. Determining the fair value of certain assets and liabilities assumed is judgmental in nature and often involves the use of significant estimates and assumptions.

Due to the application of “push-down” accounting, the Company’s financial statements and certain footnote disclosures are presented in two distinct periods to indicate the application of two different bases of accounting. Periods prior to March 26, 2012 are identified herein as “Predecessor,” while periods subsequent to the ETE Merger are identified as “Successor.”

1

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Dollars in millions)

(unaudited)

	March 31, 2013			December 31, 2012
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	—		$	—
Accounts receivable, net	79			74
Accounts receivable from related companies	123			14
Exchanges receivable	24			10
System natural gas and operating supplies	147			144
Other	19			20
Total current assets	392			262
PROPERTY, PLANT AND EQUIPMENT:
Plant in service	4,087			4,076
Construction work in progress	24			45
	4,111			4,121
Accumulated depreciation and amortization	(98		)	(57		)
Net property, plant and equipment	4,013			4,064
GOODWILL	1,785			1,785
NOTE RECEIVABLE FROM RELATED PARTY	831			831
OTHER NON-CURRENT ASSETS	114			108
Total assets	$	7,135		$	7,050

The accompanying notes are an integral part of these consolidated financial statements.

2

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Dollars in millions)

(unaudited)

	March 31, 2013			December 31, 2012
LIABILITIES AND PARTNERS’ CAPITAL
CURRENT LIABILITIES:
Current portion of long-term debt	$	255		$	258
Accounts payable	4			12
Accounts payable to related companies	56			27
Exchanges payable	145			130
Accrued taxes	17			13
Accrued interest	23			13
Other	43			69
Total current liabilities	543			522
LONG-TERM DEBT, less current portion	1,493			1,499
DEFERRED INCOME TAXES	874			853
OTHER NON-CURRENT LIABILITIES	143			135
COMMITMENTS AND CONTINGENCIES (Note 11)
PARTNERS’ CAPITAL:
Partners’ capital	4,091			4,050
Accumulated other comprehensive loss	(9		)	(9		)
Total partners’ capital	4,082			4,041
Total liabilities and partners’ capital	$	7,135		$	7,050

The accompanying notes are an integral part of these consolidated financial statements.

3

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Dollars in millions)

(unaudited)

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
OPERATING REVENUES:
Transportation and storage of natural gas	$	144		$	10		$	140
LNG terminalling	53			3			51
Other	2			—			3
Total operating revenues	199			13			194
OPERATING EXPENSES:
Operating, maintenance and general	76			35			76
Depreciation and amortization	42			3			30
Total operating expenses	118			38			106
OPERATING INCOME (LOSS)	81			(25		)	88
OTHER INCOME (EXPENSE):
Interest expense	(14		)	(1		)	(25		)
Interest income - affiliates	1			—			2
Total other expenses, net	(13		)	(1		)	(23		)
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	68			(26		)	65
Income tax expense (benefit)	26			(7		)	25
NET INCOME (LOSS)	$	42		$	(19	)	$	40

The accompanying notes are an integral part of these consolidated financial statements.

4

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Dollars in millions)

(unaudited)

	Successor					Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Net income (loss)	$	42	$	(19	)	$	40
Other comprehensive income, net of tax:
Reclassification of unrealized loss on interest rate hedges into earnings	—		—			3
	—		—			3
Comprehensive income (loss)	$	42	$	(19	)	$	43

The accompanying notes are an integral part of these consolidated financial statements.

5

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

(Dollars in millions)

(unaudited)

	Partners’ Capital			Accumulated Other Comprehensive Loss			Total
Balance, December 31, 2012	$	4,050		$	(9	)	$	4,041
Net income	42			—			42
Other	(1		)	—			(1		)
Balance, March 31, 2013	$	4,091		$	(9	)	$	4,082

The accompanying notes are an integral part of these consolidated financial statements.

6

PANHANDLE EASTERN PIPE LINE COMPANY, LP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Dollars in millions)

(unaudited)

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	42		$	(19	)	$	40
Reconciliation of net income to net cash provided by (used in)operating activities:
Depreciation and amortization	42			3			30
Deferred income taxes	21			1			19
Amortization of costs charged to interest	(8		)	—			—
Net gain on curtailment of OPEB plans benefits	—			(11		)	—
Changes in operating assets and liabilities, net of merger impact	(90		)	35			23
Net cash flows provided by operating activities	7			9			112
CASH FLOWS FROM INVESTING ACTIVITIES:
Net decrease in note receivable - related parties	—			—			255
Net increase (decrease) in income taxes payable - related parties	6			(8		)	5
Additions to property, plant and equipment	(9		)	(1		)	(28		)
Other	(1		)	—			—
Net cash flows provided by (used in) investing activities	(4		)	(9		)	232
CASH FLOWS FROM FINANCING ACTIVITIES:
Issuance of long-term debt	—			—			455
Repayment of long-term debt	—			—			(797		)
Issuance costs of debt	—			—			(2		)
Other	(3		)	—			—
Net cash flows used in financing activities	(3		)	—			(344		)
INCREASE IN CASH AND CASH EQUIVALENTS	—			—			—
CASH AND CASH EQUIVALENTS, beginning of period	—			—			—
CASH AND CASH EQUIVALENTS, end of period	$	—		$	—		$	—

The accompanying notes are an integral part of these consolidated financial statements.

7

PANHANDLE EASTERN PIPE LINE COMPANY, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Tabular dollar amounts are in millions)

(unaudited)

The accompanying unaudited interim condensed consolidated financial statements of PEPL, a Delaware limited partnership, and its subsidiaries have been prepared pursuant to the rules and regulations of the SEC for quarterly reports on Form 10-Q. These statements do not include all of the information and annual note disclosures required by GAAP, and should be read in conjunction with the Company’s financial statements and notes thereto for the year ended December 31, 2012, which are included in the Company’s Form 10-K filed with the SEC. The accompanying unaudited interim condensed consolidated financial statements have been prepared in accordance with GAAP and reflect adjustments that are, in the opinion of management, necessary for a fair statement of results for the interim period. The year-end condensed balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. Due to the seasonal nature of the Company’s operations, the results of operations and cash flows for any interim period are not necessarily indicative of the results that may be expected for the full year.

1. OPERATIONS AND ORGANIZATION:

Panhandle is primarily engaged in the interstate transportation and storage of natural gas and also provides LNG terminalling and regasification services and is subject to the rules and regulations of the FERC.  The Company’s entities include the following:

• PEPL, an indirect wholly-owned subsidiary of Southern Union, which is an indirect wholly-owned subsidiary of ETE;

• Trunkline, a direct wholly-owned subsidiary of PEPL;

• Sea Robin, an indirect wholly-owned subsidiary of PEPL;

• LNG Holdings, an indirect wholly-owned subsidiary of PEPL;

• Trunkline LNG, a direct wholly-owned subsidiary of LNG Holdings; and

• Southwest Gas, a direct wholly-owned subsidiary of PEPL.

The Company’s pipeline assets consist of interstate pipelines that transport natural gas from the Gulf of Mexico, South Texas and the panhandle regions of Texas and Oklahoma to major U.S. markets in the Midwest and Great Lakes region, as well as, owned underground storage capacity.  The Company also owns and operates an LNG import terminal located on Louisiana’s Gulf Coast, as well as, an above ground LNG storage facility.

Southern Union Panhandle, LLC, an indirect wholly-owned subsidiary of Southern Union, serves as the general partner of PEPL and owns a 1% general partnership interest in PEPL.  PEPL Holdings, an indirect wholly-owned subsidiary of Southern Union, owns a 99% limited partnership interest in PEPL.

See Note 3 for information related to the completion of the Holdco Transaction.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

There have been no changes in the Company’s accounting policies as disclosed in its Annual Report on Form 10-K for the year ended December 31, 2012. 

3. HOLDCO TRANSACTION:

On April 30, 2013, ETP acquired from ETE its interest in Holdco for 49.5 million of newly issued ETP common units and $1.40 billion in cash, less $68 million of estimated closing adjustments. Holdco is the entity formed by ETP and ETE in 2012 to own the equity interests in Southern Union and Sunoco. As a result of this transaction, ETP now owns 100% of Holdco.

8

4. RELATED PARTY TRANSACTIONS:

Accounts receivable from related companies reflected on the condensed consolidated balance sheets primarily related to services provided for Southern Union, ETE, ETP, and other affiliates. Accounts payable to related companies reflected on the condensed consolidated balance sheets primarily related to payroll funding and overhead allocation provided by ETE, ETP and other affiliates.

Pursuant to a demand note with Southern Union under a cash management program, the Company loans excess cash, net of repayments, to Southern Union.  The Company is credited with interest on the note at a one month LIBOR rate.  Given the uncertainties regarding the timing of the Company’s cash flows, including financings, capital expenditures and operating cash flows, the Company has reported the note receivable as a non-current asset.  The Company has access to the funds via the demand note and expects repayment to ultimately occur to primarily fund capital expenditures or debt retirements.

The following tables provide a summary of related party transactions for the periods presented:

	Successor					Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Transportation and storage of natural gas	$	3	$	—		$	1
Operation and maintenance and general	16		39		(1)	14
Interest Income	1		—			2

⁽¹⁾  Primarily represents corporate charges for employee expenses related to the merger with ETE offset by expenses attributable to services provided by Panhandle on behalf of affiliated companies.

5. REGULATION AND RATES:

On July 26, 2012, Trunkline filed an application with the FERC for approval to transfer approximately 770 miles of underutilized loop piping facilities by sale to an affiliate; such facilities are contemplated to be converted to crude oil transportation service. This sale is subject to FERC approval. Several parties have intervened, commented, or protested this filing and the Company is currently responding to the Commission’s requests for additional information on this application.

In November 2011, the FERC commenced an audit of PEPL to evaluate its compliance with the Uniform System of Accounts as prescribed by the FERC, annual and quarterly financial reporting to the FERC, reservation charge crediting policy and record retention. The audit is related to the period from January 1, 2010 through December 31, 2011 and is pending the issuance of a draft audit report.

6. ACCUMULATED OTHER COMPREHENSIVE LOSS:

As of March 31, 2013 and December 31, 2012, accumulated other comprehensive loss consists of net actuarial loss and prior service costs related to our OPEB plans.

7. DEBT OBLIGATIONS:

The Company has $250 million principal amount of senior notes which mature within the next twelve months. The Company currently expects to refinance all or a portion of the debt upon maturity or, alternatively, to retire all or a portion of the debt with proceeds from repayment of the note receivable from Southern Union, which funds are available to the Company on a demand basis.

Based on the estimated borrowing rates currently available to the Company and its subsidiaries for loans with similar terms and average maturities, the aggregate fair value of the Company’s consolidated debt obligations at March 31, 2013 and December 31, 2012 was $1.81 billion and $1.81 billion, respectively. As of March 31, 2013 and December 31, 2012, the aggregate carrying amount of the Company’s consolidated debt obligations was $1.75 billion and $1.76 billion, respectively.

9

The fair value of the Company’s consolidated debt obligations is a Level 2 valuation based on the observable inputs used for similar liabilities.

Term Loans.  The effective interest rate for the LNG Holdings term loan due February 2015 was 1.83% at March 31, 2013.

Other.  The Company's notes are subject to certain requirements, such as the maintenance of a fixed charge coverage ratio and a leverage ratio, which if not maintained, restrict the ability of the Company to make certain payments and impose limitations on the ability of the Company to subject its property to liens.  Other covenants impose limitations on restricted payments, including dividends and loans to affiliates, and additional indebtedness. As of March 31, 2013, the Company is in compliance with these covenants.

8. BENEFITS:

Components of Net Periodic Benefit Cost

The following tables set forth the components of net periodic benefit cost of the Company’s OPEB plans for the periods presented:

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Service cost	$	—		$	—		$	1
Interest cost	—			—			1
Expected return on plan assets	(1		)	—			(1		)
Prior service credit amortization	—			—			(1		)
Curtailment recognition (1)	—			(11		)	—
Net periodic benefit cost	$	(1	)	$	(11	)	$	—

⁽¹⁾  Subsequent to the ETE Merger, the Company amended certain of its OPEB plans to prospectively restrict participation in the plans for certain active employees.  The plan amendments resulted in the plans becoming currently over-funded and, accordingly, the Company recorded a gross pre-tax curtailment gain of $70 million, $59 million of which is subject to refund to customers; thus, the net curtailment gain recognition was $11 million.

9. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES:

The Company is exposed to certain risks in its ongoing business operations.  The primary risk managed by using derivative instruments is interest rate risk.  Interest rate swaps and treasury rate locks are the principal derivative instruments used by the Company to manage interest rate risk associated with its long-term borrowings, although other interest rate derivative contracts may also be used from time to time.  The Company recognizes all derivative assets and liabilities at fair value on the condensed consolidated balance sheets.

Interest Rate Contracts. The Company may enter into interest rate swaps to manage its exposure to changes in interest payments on long-term debt attributable to movements in market interest rates, and may enter into treasury rate locks to manage its exposure to changes in future interest payments attributable to changes in treasury rates prior to the issuance of new long-term debt instruments.

Treasury Rate Locks.  As of March 31, 2013, the Company had no outstanding treasury rate locks.  However, certain of its treasury rate locks that settled in prior periods were associated with interest payments on outstanding long-term debt.  During the predecessor periods, these treasury rate locks were accounted for as cash flow hedges, with the effective portion of their settled value recorded in accumulated other comprehensive income and reclassified into interest expense in the same periods during which the related interest payments on long-term debt impact earnings.

10

The Company had no derivative instruments at March 31, 2013 and December 31, 2012.

The following tables summarize the location and amount (excluding income tax effects) of derivative instrument gains and losses reported in the Company’s consolidated financial statements for the periods presented:

	Successor				Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012		Period from January 1, 2012 to March 25, 2012
Cash Flow Hedges:
Reclassification of unrealized loss from accumulated other comprehensive income – increase of interest expense	$	—	$	—	$	4

10. FAIR VALUE MEASUREMENT:

The Company did not have any assets or liabilities that are measured at fair value on a recurring basis at March 31, 2013. The Company did not have any Level 3 instruments measured at fair value using significant unobservable inputs at March 31, 2013 or December 31, 2012 and there were no transfers between hierarchy levels.

The approximate fair value of the Company’s cash and cash equivalents, accounts receivable and accounts payable is equal to book value, due to their short-term nature.

11. COMMITMENTS AND CONTINGENCIES:

Litigation and Other Claims

The Company is involved in legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business.

Will Price.  Will Price, an individual, filed actions in the U.S. District Court for the District of Kansas for damages against a number of companies, including the Company, alleging mis-measurement of natural gas volumes and Btu content, resulting in lower royalties to mineral interest owners.  On September 19, 2009, the Court denied plaintiffs’ request for class certification.  Plaintiffs have filed a motion for reconsideration, which the Court denied on March 31, 2010.  The Company believes that its measurement practices conformed to the terms of its FERC natural gas tariffs, which were filed with and approved by the FERC.  As a result, the Company believes that it has meritorious defenses to the Will Price lawsuit (including FERC-related affirmative defenses, such as the filed rate/tariff doctrine, the primary/exclusive jurisdiction of the FERC, and the defense that the Company complied with the terms of its tariffs).  In the event that Plaintiffs refuse Panhandle’s pending request for voluntary dismissal, Panhandle will continue to vigorously defend the case.  The Company believes it has no liability associated with this proceeding.

Liabilities for Litigation and Other Claims

The Company records accrued liabilities for litigation and other claim costs when management believes a loss is probable and reasonably estimable.  When management believes there is at least a reasonable possibility that a material loss or an additional material loss may have been incurred, the Company discloses (i) an estimate of the possible loss or range of loss in excess of the amount accrued; or (ii) a statement that such an estimate cannot be made. As of March 31, 2013 and December 31, 2012, the Company recorded litigation and other claim-related accrued liabilities of $6 million and $6 million, respectively. The Company does not have any material litigation or other claim contingency matters assessed as probable or reasonably possible that would require disclosure in the financial statements.

Environmental Matters

The Company’s operations are subject to federal, state and local laws, rules and regulations regarding water quality, hazardous and solid waste management, air quality control and other environmental matters.  These laws, rules and regulations require the Company to conduct its operations in a specified manner and to obtain and comply with a wide variety of environmental registrations, licenses, permits, inspections and other approvals.  Failure to comply with environmental laws, rules and

11

regulations may expose the Company to significant fines, penalties and/or interruptions in operations.  The Company’s environmental policies and procedures are designed to achieve compliance with such applicable laws and regulations.  These evolving laws and regulations and claims for damages to property, employees, other persons and the environment resulting from current or past operations may result in significant expenditures and liabilities in the future.  The Company engages in a process of updating and revising its procedures for the ongoing evaluation of its operations to identify potential environmental exposures and enhance compliance with regulatory requirements.

Environmental Remediation

The Company is responsible for environmental remediation at certain sites on its natural gas transmission systems for contamination resulting from the past use of lubricants containing PCBs in compressed air systems; the past use of paints containing PCBs; and the prior use of wastewater collection facilities and other on-site disposal areas.  The Company has implemented a program to remediate such contamination.  The primary remaining remediation activity on the Panhandle systems is associated with past use of paints containing PCBs or PCB impacts to equipment surfaces and to a building at one location. The PCB assessments are ongoing and the related estimated remediation costs are subject to further change.

Other remediation typically involves the management of contaminated soils and may involve remediation of groundwater.  Activities vary with site conditions and locations, the extent and nature of the contamination, remedial requirements, complexity and sharing of responsibility.  The ultimate liability and total costs associated with these sites will depend upon many factors.  If remediation activities involve statutory joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Company could potentially be held responsible for contamination caused by other parties.  In some instances, the Company may share liability associated with contamination with other potentially responsible parties.  The Company may also benefit from contractual indemnities that cover some or all of the cleanup costs.  These sites are generally managed in the normal course of business or operations.

The Company’s environmental remediation activities are undertaken in cooperation with and under the oversight of appropriate regulatory agencies, enabling the Company under certain circumstances to take advantage of various voluntary cleanup programs in order to perform the remediation in the most effective and efficient manner.

Environmental Remediation Liabilities

The table below reflects the amount of accrued liabilities recorded on the condensed consolidated balance sheets at the dates indicated to cover environmental remediation actions where management believes a loss is probable and reasonably estimable.  The Company does not have any material environmental remediation matters assessed as reasonably possible.

	March 31, 2013		December 31, 2012
Current	$	1	$	1
Non-current	5		5
Total environmental liabilities	$	6	$	6

Other Commitments and Contingencies

Controlled Group Pension Liabilities.  Southern Union (including certain of its divisions) sponsors a number of defined benefit pension plans for employees.  Under applicable pension and tax laws, upon being acquired by Southern Union, the Company became a member of Southern Union’s “controlled group” with respect to those plans and, along with Southern Union and any other members of that group, is jointly and severally liable for any failure by Southern Union (along with any other persons that may be or become a sponsor of any such plan) to fund any of these pension plans or to pay any unfunded liabilities that these plans may have if they are ever terminated.  In addition, if any of the obligations of any of these pension plans is not paid when due, a lien in favor of that plan or the Pension Benefit Guaranty Corporation may be created against the assets of each member of Southern Union’s controlled group, including the Company and each of its subsidiaries.  Based on the latest actuarial information available, the aggregate amount of the projected benefit obligations of these pension plans was approximately $243 million and the estimated fair value of all of the assets of these plans was approximately $155 million.

12

Unclaimed Property Audits.  The Company is subject to the laws and regulations of states and other jurisdictions concerning the identification, reporting and escheatment (the transfer of property to the state) of unclaimed or abandoned funds, and is subject to audit and examination for compliance with these requirements.  The Company is currently being examined by a third party auditor on behalf of nine states for compliance with unclaimed property laws.

See Note 5 for other potential regulatory matters applicable to the Company.

Future Regulatory Compliance Commitments

Air Quality Control.   On April 17, 2012 the EPA issued the Oil and Natural Gas Sector New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants (“HAP”).  The standards revise the new source performance standards for volatile organic compounds from leaking components at onshore natural gas processing plants and new source performance standards for sulfur dioxide emissions from natural gas processing plants.  The EPA also established standards for certain oil and gas operations not covered by the existing standards.  In addition to the operations covered by the existing standards, the newly established standards regulate volatile organic compound emissions from gas wells, centrifugal compressors, reciprocating compressors, pneumatic controllers and storage vessels.  The Company is reviewing the new standards to determine the impact on its operations.

In August 2010, the EPA finalized a rule that requires reductions in a number of pollutants, including formaldehyde and carbon monoxide, for certain engines regardless of size at Area Sources (sources that emit less than 10 tons per year of any one HAP or 25 tons per year of all HAPs) and engines less than 500 horsepower at Major Sources (sources that emit 10 tons per year or more of any one HAP or 25 tons per year of all HAPs).  Compliance is required by October 2013.  It is anticipated that the limits adopted in this rule will be used in a future EPA rule that is scheduled to be finalized in 2013, with compliance required in 2016.  This future rule is expected to require reductions in formaldehyde and carbon monoxide emissions from engines greater than 500 horsepower at Major Sources.

Nitrogen oxides are the primary air pollutant from natural gas-fired engines.  Nitrogen oxide emissions may form ozone in the atmosphere.  In 2008, the EPA lowered the ozone standard to 75 ppb with compliance anticipated in 2013 to 2015.  In January 2010, the EPA proposed lowering the standard to 60 to 70 ppb in lieu of the 75 ppb standard, with compliance required in 2014 or later.  In September 2011, the EPA decided to rescind the proposed lower ozone standard and begin the process to implement the 75 ppb ozone standard established in 2008.

In January 2010, the EPA finalized a 100 ppb one-hour nitrogen dioxide standard. The rule requires the installation of new nitrogen dioxide monitors in urban communities and roadways by 2013.  This new monitoring may result in additional nitrogen dioxide non-attainment areas.  In addition, ambient air quality modeling may be required to demonstrate compliance with the new standard.

The Company is currently reviewing the potential impacts of the August 2010 Area Source National Emissions Standards for Hazardous Air Pollutants rule, implementation of the 2008 ozone standard and the new nitrogen dioxide standard on its operations and the potential costs associated with the installation of emission control systems on its existing engines.  The ultimate costs associated with these activities cannot be estimated with any certainty at this time, but the Company believes, based on the current understanding of the current and proposed rules, such costs will not have a material adverse effect on its consolidated financial position, results of operations or cash flows.

13

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

(Tabular dollar amounts are in millions)

Introduction

The information in Item 2 has been prepared pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q. Accordingly, this Item 2 includes only management’s narrative analysis of the results of operations and certain supplemental information.

References to “we”, “us”, “our”, the “Company” and “Panhandle” shall mean Panhandle Eastern Pipe Line Company, LP and its subsidiaries.

Overview

The Company’s business purpose is to provide interstate transportation and storage of natural gas in a safe, efficient and dependable manner.  The Company operates approximately 10,000 miles of interstate pipelines that transport up to 6.4 Bcf/d of natural gas.  Demand for natural gas transmission services on the Company’s pipeline system is seasonal, with the highest throughput and a higher portion of annual total operating revenues occurring in the traditional winter heating season, which occurs during the first and fourth calendar quarters.

The Company’s business is conducted through both short- and long-term contracts with customers.  Short-term and long-term contracts are affected by changes in market conditions and competition with other pipelines, changing supply sources and volatility in natural gas prices and basis differentials.  Since the majority of the Company’s revenues are related to firm capacity reservation charges, which customers pay whether they utilize their contracted capacity or not, volumes transported do not have as significant an impact on revenues over the short-term.  However, longer-term demand for capacity may be affected by changes in the customers’ actual and anticipated utilization of their contracted capacity and other factors.

The Company’s regulated transportation and storage businesses can file (or be required to file) for changes in their rates, which are subject to approval by the FERC.  Although a significant portion of the Company’s contracts are discounted or negotiated rate contracts, changes in rates and other tariff provisions resulting from regulatory proceedings have the potential to impact negatively the Company’s results of operations and financial condition.

RECENT DEVELOPMENTS

Holdco Transaction

On April 30, 2013, ETP acquired from ETE its interest in Holdco for 49.5 million of newly issued ETP common units and $1.40 billion in cash, less $68 million of estimated closing adjustments. Holdco is the entity formed by ETP and ETE in 2012 to own the equity interests in Southern Union and Sunoco. As a result of this transaction, ETP now owns 100% of Holdco.

Results of Operations

The ETE Merger, which was completed on March 26, 2012, was accounted for by ETE using business combination accounting.  The Company allocated the purchase price paid by ETE to its assets, liabilities and partners’ capital as of the acquisition date based on preliminary estimates.  Accordingly, the successor financial statements reflect a new basis of accounting and predecessor and successor period financial results (separated by a heavy black line) are presented, but are not comparable.

The most significant impacts of the new basis of accounting during the successor periods were (i) higher depreciation expense due to the step-up of depreciable assets and assignment of purchase price to certain amortizable intangible assets and (ii) lower interest expense (though not cash payments) for the remaining life of the related long-term debt due to its revaluation and related debt premium amortization. Depreciation and amortization expense recognized in the successor periods subsequent to March 25, 2012 increased by approximately $8 million per quarter as a direct result of the application of the new basis of accounting. Interest expense recognized in the successor periods subsequent to March 25, 2012 decreased by approximately $8 million per quarter as a direct result of the application of the new basis of accounting.

The results of operations for the successor and predecessor periods reflect certain merger-related expenses, which are not expected to have a continuing impact on the results going forward, and those amounts are discussed in the results below.

14

The following table illustrates the results of operations of the Company for the periods presented:

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
OPERATING REVENUES:
Transportation and storage of natural gas	$	144		$	10		$	140
LNG terminalling	53			3			51
Other	2			—			3
Total operating revenues (1)	199			13			194
OPERATING EXPENSES:
Operating, maintenance and general	76			35			76
Depreciation and amortization	42			3			30
Total operating expenses	118			38			106
OPERATING INCOME (LOSS)	81			(25		)	88
OTHER INCOME (EXPENSE):
Interest expense	(14		)	(1		)	(25		)
Interest income - affiliates	1			—			2
Total other expenses, net	(13		)	(1		)	(23		)
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	68			(26		)	65
Income tax expense (benefit)	26			(7		)	25
NET INCOME (LOSS)	$	42		$	(19	)	$	40
Panhandle natural gas volumes transported (TBtu): (2)
PEPL	177			9			152
Trunkline	180			12			177
Sea Robin	40			2			20

⁽¹⁾  Reservation revenues comprised 89% of total operating revenues for the period ended March 31, 2013. Reservation revenues comprised 88% and 88% of total operating revenues for the periods from March 26, 2012 to March 31, 2012 and January 1, 2012 to March 25, 2012, respectively.

⁽²⁾  Includes transportation deliveries made throughout the Company’s pipeline network.

The following is a discussion of the significant items and variances impacting the Company’s net income during the periods presented above:

• Operating Revenues. Operating revenues for the three months ended March 31, 2013 decreased compared to the successor and predecessor periods in 2012 primarily due to lower capacity sold at lower rates and lower parking revenues, the impacts from which were partially offset by higher usage revenues as a result of higher volumes.

• Operating Expenses. The period from March 26, 2012 to March 31, 2012 included merger-related expenses of approximately $41 million, offset by a curtailment gain on our OPEB plans of $11 million. The successor periods also reflected higher depreciation due to the step-up in depreciable assets in connection with the ETE Merger and lower corporate allocations due to merger-related synergies.

• Interest Expense. Interest expense was lower in the three months ended March 31, 2013 primarily due to amortization of the long-term debt fair value adjustment recorded in connection with the ETE Merger as well as the termination of interest rate swaps.

• Income Taxes. The effective income tax rate for the period from March 26,2012 to March 31, 2012 was lower than the other periods presented above as a result of non-deductible executive compensation expenses included in the merger-related expenses.

15

Supplemental Pro Forma Financial Information

The following unaudited pro forma consolidated financial information of the Company has been prepared in accordance with Article 11 of Regulation S-X and reflects the pro forma impacts of the ETE Merger for the three months ended ended March 31, 2012, giving effect to the ETE Merger as if it had occurred on January 1, 2012. This unaudited pro forma financial information is provided to supplement the discussion and analysis of the historical financial information and should be read in conjunction with such historical financial information. This unaudited pro forma information is for illustrative purposes only and is not necessarily indicative of the financial results that would have occurred if the ETE Merger had been consummated on January 1, 2012.

	Successor			Predecessor
	Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012			Pro Forma Adjustments				Pro Forma Three Months Ended March 31, 2012
OPERATING REVENUES	$	13		$	194		$	—			$	207
OPERATING EXPENSES:
Operating, maintenance and general	35			76			(30		)	(a)	81
Depreciation and amortization	3			30			8			(b)	41
Total operating expenses	38			106			(22		)		122
OPERATING INCOME (LOSS)	(25		)	88			22				85
OTHER INCOME (EXPENSE):
Interest (expense) benefit	(1		)	(25		)	8			(c)	(18		)
Interest income - affiliates	—			2			—				2
Total other (expenses) benefit, net	(1		)	(23		)	8				(16		)
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	(26		)	65			30				69
Income tax expense (benefit)	(7		)	25			3			(d)	21
NET (LOSS) INCOME	$	(19	)	$	40		$	27			$	48

(a) To eliminate the merger-related costs incurred by the Company in connection with the ETE Merger, including change in control and severance costs. These costs are eliminated from the Company’s pro forma income statement because such costs would not have a continuing impact on the Company’s results of operations.

(b) To record incremental depreciation on the excess purchase price allocated to property, plant and equipment based on a weighted average useful life of 24 years.

(c) To adjust amortization included in interest expense to (i) reverse historical amortization of financing costs and fair value adjustments related to debt and (ii) record pro forma amortization related to the pro forma adjustment of the Company’s debt to fair value.

(d) To reflect income tax impacts from the pro forma adjustments to pre-tax income, including the elimination of the dividend received deduction recorded in the historical income tax provision for the predecessor periods in connection with the Company’s investment in Citrus.

16

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Item 3, Quantitative and Qualitative Disclosures About Market Risk, has been 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

The Company has established disclosure controls and procedures to ensure that information required to be disclosed by the Company, including consolidated entities, in reports filed or submitted under the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. The Company’s disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports it files or submits under the Exchange Act is accumulated and communicated to management, including the Company’s COO and CFO, as appropriate, to allow timely decisions regarding required disclosure. The Company performed an evaluation under the supervision and with the participation of management, including its COO and CFO, and with the participation of personnel from its Legal, Internal Audit, Risk Management and Financial Reporting Departments, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Exchange Act Rule 13a-15(e)) as of the end of the period covered by this report. Based on that evaluation, Panhandle’s COO and CFO concluded that the Company’s disclosure controls and procedures were effective as of March 31, 2013.

Changes in Internal Control over Financial Reporting

Subsequent to the merger with ETE in March 2012, the Partnership's internal controls over financial reporting, including certain disclosure controls and corporate governance procedures, have been impacted by changes made to conform to the existing controls of ETP and ETE. During the three months ended March 31, 2013, the Partnership's accounting systems were transitioned to the accounting systems of ETP and ETE and accordingly certain controls changed at that time.  None of these changes are in response to any identified deficiency or weakness in the Partnership's internal control over financial reporting.

There were no other changes in the Partnership's internal controls over financial reporting that have materially affected, or are reasonably likely to affect, its internal controls over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Company is a party to or has property subject to litigation and other proceedings, including matters arising under provisions relating to the protection of the environment, as described in Note 11 in this Quarterly Report on Form 10-Q and in Note 15 in the Company’s Form 10-K for the year ended December 31, 2012.

The Company is subject to federal and state requirements for the protection of the environment, including those for the discharge of hazardous materials and remediation of contaminated sites. As a result, the Company is a party to or has its property subject to various other lawsuits or proceedings involving environmental protection matters. For information regarding these matters, see Note 11 in this Quarterly Report on Form 10-Q and Note 15 included in the Company’s Form 10-K for the year ended December 31, 2012.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors previously disclosed in the Company’s Form 10-K filed with the SEC on March 1, 2013.

17

ITEM 6. EXHIBITS

The following exhibits are filed as part of this Quarterly Report on Form 10-Q:

Exhibit No.
31.1	Certificate by Principal Executive Officer pursuant to Rule 13a – 14(a) or 15d – 14(a) promulgated under the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certificate by Principle Financial Officer pursuant to Rule 13a – 14(a) or 15d – 14(a) promulgated under the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certificate by Principle Executive Officer pursuant to Rule 13a – 14(b) or 15d – 14(b) promulgated under the Securities Exchange Act of 1934 and Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350.
32.2	Certificate by Principle Financial Officer pursuant to Rule 13a – 14(b) or 15d – 14(b) promulgated under the Securities Exchange Act of 1934 and Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350.
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definitions Document
101.LAB	XBRL Taxonomy Label Linkbase Document
101.PRE	XBRL Taxonomy Presentation Linkbase Document

18

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, Panhandle Eastern Pipe Line Company, LP has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		PANHANDLE EASTERN PIPE LINE COMPANY, LP
Date:	May 9, 2013	By: /s/   MARTIN SALINAS, JR. Martin Salinas, Jr. Chief Financial Officer (duly authorized to sign on behalf of the registrant)

19

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

RULES 13A-14(a) AND 15D-14(a) UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Kelcy L. Warren, certify that:

(1) I have reviewed this Report on Form 10-Q of Panhandle Eastern Pipe Line Company, LP;

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

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

(4) The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

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

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

(5) The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2013

/s/ KELCY L. WARREN

Kelcy L. Warren

Chief Executive Officer

(principal executive officer)

EX-31.2

Exhibit 31.2

CERTIFICATION PURSUANT TO

RULES 13A-14(a) AND 15D-14(a) UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Martin Salinas, Jr., certify that:

(1) I have reviewed this Report on Form 10-Q of Panhandle Eastern Pipe Line Company, LP;

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

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

(4) The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

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

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

(5) The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 9, 2013

/s/ MARTIN SALINAS, JR.

Martin Salinas, Jr.

Chief Financial Officer

(principal financial officer)

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Form 10-Q of Panhandle Eastern Pipe Line Company, LP (the “Company”) for the quarter ended March 31, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Kelcy L. Warren, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge (i) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, except as otherwise noted under Item 9A therein, and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ KELCY L. WARREN

Kelcy L. Warren

Chief Executive Officer

May 9, 2013

This Certification is being furnished solely to accompany the Report pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, and shall not be deemed “filed” by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and shall not be incorporated by reference into any filing of the Company under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, whether made before or after the date of this Report, irrespective of any general incorporation language contained in such filing.

A signed original of this written statement required by Section 906, or other documents authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Form 10-Q of Panhandle Eastern Pipe Line Company, LP (the “Company”) for the quarter ended March 31, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Martin Salinas, Jr., Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge (i) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended, except as otherwise noted under Item 9A therein, and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ MARTIN SALINAS, JR.

Martin Salinas, Jr.

Chief Financial Officer

May 9, 2013

This Certification is being furnished solely to accompany the Report pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, and shall not be deemed “filed” by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and shall not be incorporated by reference into any filing of the Company under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, whether made before or after the date of this Report, irrespective of any general incorporation language contained in such filing.

A signed original of this written statement required by Section 906, or other documents authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Debt Obligations - Narrative (Details) (USD $)	Mar. 31, 2013	Dec. 31, 2012
Term Loan Due August 2013
Debt Instrument
Long term debt, face amount	$ 250,000,000
Estimate of Fair Value, Fair Value Disclosure
Debt Instrument
Debt Instrument, Fair Value Disclosure	1,810,000,000	1,810,000,000
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Debt Instrument
Long term debt, amount outstanding	$ 1,750,000,000	$ 1,760,000,000
Panhandle [Member] | Term Loan 2015 [Member]
Debt Instrument
Debt, Weighted Average Interest Rate	1.83%

XML

Holdco Transaction

3 Months Ended

Mar. 31, 2013

Business Combinations [Abstract]

ETE Merger and ETP Merger

HOLDCO TRANSACTION:

On April 30, 2013, ETP acquired from ETE its interest in Holdco for 49.5 million of newly issued ETP common units and $1.40 billion in cash, less $68 million of estimated closing adjustments. Holdco is the entity formed by ETP and ETE in 2012 to own the equity interests in Southern Union and Sunoco. As a result of this transaction, ETP now owns 100% of Holdco.

XML

Commitments and Contingencies - Accrued Liabilities (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Loss Contingencies
Current	$ 1	$ 1
Non-current	5	5
Total environmental liabilities	$ 6	$ 6

XML

Commitment and Contingenices (Narrative) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Loss Contingencies
Estimated litigation liability	$ 6	$ 6
Aggregate amount of projected benefit obligations of pension plans		243
Estimated fair value of all assets of pension plans		$ 155

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Summary of Significant Accounting Policies (Notes)

3 Months Ended

Mar. 31, 2013

Accounting Policies [Abstract]

Significant Accounting Policies

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:

There have been no changes in the Company’s accounting policies as disclosed in its Annual Report on Form 10-K for the year ended December 31, 2012.

XML

CONSOLIDATED BALANCE SHEETS (USD $) In Millions, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
CURRENT ASSETS:
Cash and cash equivalents	$ 0	$ 0
Accounts receivable, net	79	74
Accounts receivable from related companies	123	14
Exchanges receivable	24	10
System natural gas and operating supplies	147	144
Other	19	20
Total current assets	392	262
PROPERTY, PLANT AND EQUIPMENT:
Plant in service	4,087	4,076
Construction work in progress	24	45
Total property, plant and equipment	4,111	4,121
Accumulated depreciation and amortization	(98)	(57)
Net property, plant and equipment	4,013	4,064
GOODWILL	1,785	1,785
NOTE RECEIVABLE FROM RELATED PARTY	831	831
OTHER NON-CURRENT ASSETS	114	108
Total assets	7,135	7,050
CURRENT LIABILITIES:
Current portion of long-term debt	255	258
Accounts payable	4	12
Accounts payable to related companies	56	27
Exchanges payable	145	130
Accrued taxes	17	13
Accrued interest	23	13
Other	43	69
Total current liabilities	543	522
LONG-TERM DEBT, less current portion	1,493	1,499
DEFERRED INCOME TAXES	874	853
OTHER NON-CURRENT LIABILITIES	143	135
COMMITMENTS AND CONTINGENCIES (Note 11)
PARTNERS’ CAPITAL:
Partners’ capital	4,091	4,050
Accumulated other comprehensive loss	(9)	(9)
Total partners’ capital	4,082	4,041
Total liabilities and partners’ capital	$ 7,135	$ 7,050

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended
	Mar. 31, 2012 Successor	Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ (19)	$ 42	$ 40
Reconciliation of net income to net cash provided by (used in)operating activities:
Depreciation and amortization	3	42	30
Deferred income taxes	1	21	19
Amortization of costs charged to interest	0	(8)	0
Net gain on curtailment of OPEB plans benefits	(11)	0	0
Changes in operating assets and liabilities, net of merger impact	35	(90)	23
Net cash flows provided by operating activities	9	7	112
CASH FLOWS FROM INVESTING ACTIVITIES:
Net decrease in note receivable - related parties	0	0	255
Net increase (decrease) in income taxes payable - related parties	(8)	6	5
Additions to property, plant and equipment	(1)	(9)	(28)
Other	0	(1)	0
Net cash flows provided by (used in) investing activities	(9)	(4)	232
CASH FLOWS FROM FINANCING ACTIVITIES:
Issuance of long-term debt	0	0	455
Repayment of long-term debt	0	0	(797)
Issuance costs of debt	0	0	(2)
Other	0	(3)	0
Net cash flows used in financing activities	0	(3)	(344)
INCREASE IN CASH AND CASH EQUIVALENTS	0	0	0
CASH AND CASH EQUIVALENTS, beginning of period	0	0	0
CASH AND CASH EQUIVALENTS, end of period	$ 0	$ 0	$ 0

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Description of the Business (Details)	3 Months Ended
	Mar. 31, 2013
General partnership
Description of the Business
General partnership interest	1.00%
Limited partnership
Description of the Business
Limited partnership interest	99.00%

XML

Related Party Transactions (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended		3 Months Ended
	Mar. 31, 2012 Successor		Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
Related Party Transaction
Transportation and storage of natural gas	$ 0		$ 3	$ 1
Operation and maintenance and general	39	[1]	16	14
Interest Income	$ 0		$ 1	$ 2

[1] Primarily represents corporate charges for employee expenses related to the merger with ETE offset by expenses attributable to services provided by Panhandle on behalf of affiliated companies.

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Description of the Business

3 Months Ended

Mar. 31, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Description of the Business

OPERATIONS AND ORGANIZATION:

Panhandle is primarily engaged in the interstate transportation and storage of natural gas and also provides LNG terminalling and regasification services and is subject to the rules and regulations of the FERC.  The Company’s entities include the following:

• PEPL, an indirect wholly-owned subsidiary of Southern Union, which is an indirect wholly-owned subsidiary of ETE;

• Trunkline, a direct wholly-owned subsidiary of PEPL;

• Sea Robin, an indirect wholly-owned subsidiary of PEPL;

• LNG Holdings, an indirect wholly-owned subsidiary of PEPL;

• Trunkline LNG, a direct wholly-owned subsidiary of LNG Holdings; and

• Southwest Gas, a direct wholly-owned subsidiary of PEPL.

The Company’s pipeline assets consist of interstate pipelines that transport natural gas from the Gulf of Mexico, South Texas and the panhandle regions of Texas and Oklahoma to major U.S. markets in the Midwest and Great Lakes region, as well as, owned underground storage capacity.  The Company also owns and operates an LNG import terminal located on Louisiana’s Gulf Coast, as well as, an above ground LNG storage facility.

Southern Union Panhandle, LLC, an indirect wholly-owned subsidiary of Southern Union, serves as the general partner of PEPL and owns a 1% general partnership interest in PEPL.  PEPL Holdings, an indirect wholly-owned subsidiary of Southern Union, owns a 99% limited partnership interest in PEPL.

See Note 3 for information related to the completion of the Holdco Transaction.

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended
	Mar. 31, 2012 Successor	Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
OPERATING REVENUES:
Transportation and storage of natural gas	$ 10	$ 144	$ 140
LNG terminalling	3	53	51
Other	0	2	3
Total operating revenues	13	199	194
OPERATING EXPENSES:
Operating, maintenance and general	35	76	76
Depreciation and amortization	3	42	30
Total operating expenses	38	118	106
OPERATING INCOME (LOSS)	(25)	81	88
OTHER INCOME (EXPENSE):
Interest expense	(1)	(14)	(25)
Interest income - affiliates	0	1	2
Total other expenses, net	(1)	(13)	(23)
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	(26)	68	65
Income tax expense (benefit)	(7)	26	25
NET INCOME (LOSS)	$ (19)	$ 42	$ 40

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies [Abstract]

Commitments and Contingencies Disclosure

COMMITMENTS AND CONTINGENCIES:

Litigation and Other Claims

The Company is involved in legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business.

Will Price.  Will Price, an individual, filed actions in the U.S. District Court for the District of Kansas for damages against a number of companies, including the Company, alleging mis-measurement of natural gas volumes and Btu content, resulting in lower royalties to mineral interest owners.  On September 19, 2009, the Court denied plaintiffs’ request for class certification.  Plaintiffs have filed a motion for reconsideration, which the Court denied on March 31, 2010.  The Company believes that its measurement practices conformed to the terms of its FERC natural gas tariffs, which were filed with and approved by the FERC.  As a result, the Company believes that it has meritorious defenses to the Will Price lawsuit (including FERC-related affirmative defenses, such as the filed rate/tariff doctrine, the primary/exclusive jurisdiction of the FERC, and the defense that the Company complied with the terms of its tariffs).  In the event that Plaintiffs refuse Panhandle’s pending request for voluntary dismissal, Panhandle will continue to vigorously defend the case.  The Company believes it has no liability associated with this proceeding.

Liabilities for Litigation and Other Claims

The Company records accrued liabilities for litigation and other claim costs when management believes a loss is probable and reasonably estimable.  When management believes there is at least a reasonable possibility that a material loss or an additional material loss may have been incurred, the Company discloses (i) an estimate of the possible loss or range of loss in excess of the amount accrued; or (ii) a statement that such an estimate cannot be made. As of March 31, 2013 and December 31, 2012, the Company recorded litigation and other claim-related accrued liabilities of $6 million and $6 million, respectively. The Company does not have any material litigation or other claim contingency matters assessed as probable or reasonably possible that would require disclosure in the financial statements.

Environmental Matters

The Company’s operations are subject to federal, state and local laws, rules and regulations regarding water quality, hazardous and solid waste management, air quality control and other environmental matters.  These laws, rules and regulations require the Company to conduct its operations in a specified manner and to obtain and comply with a wide variety of environmental registrations, licenses, permits, inspections and other approvals.  Failure to comply with environmental laws, rules and regulations may expose the Company to significant fines, penalties and/or interruptions in operations.  The Company’s environmental policies and procedures are designed to achieve compliance with such applicable laws and regulations.  These evolving laws and regulations and claims for damages to property, employees, other persons and the environment resulting from current or past operations may result in significant expenditures and liabilities in the future.  The Company engages in a process of updating and revising its procedures for the ongoing evaluation of its operations to identify potential environmental exposures and enhance compliance with regulatory requirements.

Environmental Remediation

The Company is responsible for environmental remediation at certain sites on its natural gas transmission systems for contamination resulting from the past use of lubricants containing PCBs in compressed air systems; the past use of paints containing PCBs; and the prior use of wastewater collection facilities and other on-site disposal areas.  The Company has implemented a program to remediate such contamination.  The primary remaining remediation activity on the Panhandle systems is associated with past use of paints containing PCBs or PCB impacts to equipment surfaces and to a building at one location. The PCB assessments are ongoing and the related estimated remediation costs are subject to further change.

Other remediation typically involves the management of contaminated soils and may involve remediation of groundwater.  Activities vary with site conditions and locations, the extent and nature of the contamination, remedial requirements, complexity and sharing of responsibility.  The ultimate liability and total costs associated with these sites will depend upon many factors.  If remediation activities involve statutory joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Company could potentially be held responsible for contamination caused by other parties.  In some instances, the Company may share liability associated with contamination with other potentially responsible parties.  The Company may also benefit from contractual indemnities that cover some or all of the cleanup costs.  These sites are generally managed in the normal course of business or operations.

The Company’s environmental remediation activities are undertaken in cooperation with and under the oversight of appropriate regulatory agencies, enabling the Company under certain circumstances to take advantage of various voluntary cleanup programs in order to perform the remediation in the most effective and efficient manner.

Environmental Remediation Liabilities

The table below reflects the amount of accrued liabilities recorded on the condensed consolidated balance sheets at the dates indicated to cover environmental remediation actions where management believes a loss is probable and reasonably estimable.  The Company does not have any material environmental remediation matters assessed as reasonably possible.

	March 31, 2013		December 31, 2012
Current	$	1	$	1
Non-current	5		5
Total environmental liabilities	$	6	$	6

Other Commitments and Contingencies

Controlled Group Pension Liabilities.  Southern Union (including certain of its divisions) sponsors a number of defined benefit pension plans for employees.  Under applicable pension and tax laws, upon being acquired by Southern Union, the Company became a member of Southern Union’s “controlled group” with respect to those plans and, along with Southern Union and any other members of that group, is jointly and severally liable for any failure by Southern Union (along with any other persons that may be or become a sponsor of any such plan) to fund any of these pension plans or to pay any unfunded liabilities that these plans may have if they are ever terminated.  In addition, if any of the obligations of any of these pension plans is not paid when due, a lien in favor of that plan or the Pension Benefit Guaranty Corporation may be created against the assets of each member of Southern Union’s controlled group, including the Company and each of its subsidiaries.  Based on the latest actuarial information available, the aggregate amount of the projected benefit obligations of these pension plans was approximately $243 million and the estimated fair value of all of the assets of these plans was approximately $155 million.

Unclaimed Property Audits.  The Company is subject to the laws and regulations of states and other jurisdictions concerning the identification, reporting and escheatment (the transfer of property to the state) of unclaimed or abandoned funds, and is subject to audit and examination for compliance with these requirements.  The Company is currently being examined by a third party auditor on behalf of nine states for compliance with unclaimed property laws.

See Note 5 for other potential regulatory matters applicable to the Company.

Future Regulatory Compliance Commitments

Air Quality Control.   On April 17, 2012 the EPA issued the Oil and Natural Gas Sector New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants (“HAP”).  The standards revise the new source performance standards for volatile organic compounds from leaking components at onshore natural gas processing plants and new source performance standards for sulfur dioxide emissions from natural gas processing plants.  The EPA also established standards for certain oil and gas operations not covered by the existing standards.  In addition to the operations covered by the existing standards, the newly established standards regulate volatile organic compound emissions from gas wells, centrifugal compressors, reciprocating compressors, pneumatic controllers and storage vessels.  The Company is reviewing the new standards to determine the impact on its operations.

In August 2010, the EPA finalized a rule that requires reductions in a number of pollutants, including formaldehyde and carbon monoxide, for certain engines regardless of size at Area Sources (sources that emit less than 10 tons per year of any one HAP or 25 tons per year of all HAPs) and engines less than 500 horsepower at Major Sources (sources that emit 10 tons per year or more of any one HAP or 25 tons per year of all HAPs).  Compliance is required by October 2013.  It is anticipated that the limits adopted in this rule will be used in a future EPA rule that is scheduled to be finalized in 2013, with compliance required in 2016.  This future rule is expected to require reductions in formaldehyde and carbon monoxide emissions from engines greater than 500 horsepower at Major Sources.

Nitrogen oxides are the primary air pollutant from natural gas-fired engines.  Nitrogen oxide emissions may form ozone in the atmosphere.  In 2008, the EPA lowered the ozone standard to 75 ppb with compliance anticipated in 2013 to 2015.  In January 2010, the EPA proposed lowering the standard to 60 to 70 ppb in lieu of the 75 ppb standard, with compliance required in 2014 or later.  In September 2011, the EPA decided to rescind the proposed lower ozone standard and begin the process to implement the 75 ppb ozone standard established in 2008.

In January 2010, the EPA finalized a 100 ppb one-hour nitrogen dioxide standard. The rule requires the installation of new nitrogen dioxide monitors in urban communities and roadways by 2013.  This new monitoring may result in additional nitrogen dioxide non-attainment areas.  In addition, ambient air quality modeling may be required to demonstrate compliance with the new standard.

The Company is currently reviewing the potential impacts of the August 2010 Area Source National Emissions Standards for Hazardous Air Pollutants rule, implementation of the 2008 ozone standard and the new nitrogen dioxide standard on its operations and the potential costs associated with the installation of emission control systems on its existing engines.  The ultimate costs associated with these activities cannot be estimated with any certainty at this time, but the Company believes, based on the current understanding of the current and proposed rules, such costs will not have a material adverse effect on its consolidated financial position, results of operations or cash flows.

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Document And Entity Information	3 Months Ended
	Mar. 31, 2013
Document Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Entity Registrant Name	Panhandle Eastern Pipe Line Co LP
Entity Central Index Key	0000076063
Document Period End Date	Mar. 31, 2013
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q1
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2013

Related Party Transactions [Abstract]

Related Party Transactions [table text block]

The following tables provide a summary of related party transactions for the periods presented:

	Successor					Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Transportation and storage of natural gas	$	3	$	—		$	1
Operation and maintenance and general	16		39		(1)	14
Interest Income	1		—			2

⁽¹⁾  Primarily represents corporate charges for employee expenses related to the merger with ETE offset by expenses attributable to services provided by Panhandle on behalf of affiliated companies.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended
	Mar. 31, 2012 Successor	Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
Statement of Income and Comprehensive Income
Net income (loss)	$ (19)	$ 42	$ 40
Other comprehensive income (loss), net of tax:
Reclassification of unrealized loss on interest rate hedges into earnings	0	0	3
Total other comprehensive income, net of tax	0	0	3
Comprehensive income (loss)	$ (19)	$ 42	$ 43

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Comprehensive Income

3 Months Ended

Mar. 31, 2013

Statement of Other Comprehensive Income [Abstract]

Comprehensive Income

ACCUMULATED OTHER COMPREHENSIVE LOSS:

As of March 31, 2013 and December 31, 2012, accumulated other comprehensive loss consists of net actuarial loss and prior service costs related to our OPEB plans.

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Regulatory Matters

3 Months Ended

Mar. 31, 2013

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities [Abstract]

Regulatory Matters

REGULATION AND RATES:

On July 26, 2012, Trunkline filed an application with the FERC for approval to transfer approximately 770 miles of underutilized loop piping facilities by sale to an affiliate; such facilities are contemplated to be converted to crude oil transportation service. This sale is subject to FERC approval. Several parties have intervened, commented, or protested this filing and the Company is currently responding to the Commission’s requests for additional information on this application.

In November 2011, the FERC commenced an audit of PEPL to evaluate its compliance with the Uniform System of Accounts as prescribed by the FERC, annual and quarterly financial reporting to the FERC, reservation charge crediting policy and record retention. The audit is related to the period from January 1, 2010 through December 31, 2011 and is pending the issuance of a draft audit report.

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Holdco Transaction (Narrative) (Details) (USD $) Share data in Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2013 Holdco ETP	Mar. 21, 2013 Holdco Acquisition
Business Acquisition
Business Acquisition Units Acquired		49.5
Business Acquisition, Cost of Acquired Entity, Cash Paid		$ 1,400,000,000
Estimated Closing Adjustments		$ 68,000,000
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%

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Benefits (Tables)

3 Months Ended

Mar. 31, 2013

Postemployment Benefits [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

The following tables set forth the components of net periodic benefit cost of the Company’s OPEB plans for the periods presented:

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Service cost	$	—		$	—		$	1
Interest cost	—			—			1
Expected return on plan assets	(1		)	—			(1		)
Prior service credit amortization	—			—			(1		)
Curtailment recognition (1)	—			(11		)	—
Net periodic benefit cost	$	(1	)	$	(11	)	$	—

⁽¹⁾  Subsequent to the ETE Merger, the Company amended certain of its OPEB plans to prospectively restrict participation in the plans for certain active employees.  The plan amendments resulted in the plans becoming currently over-funded and, accordingly, the Company recorded a gross pre-tax curtailment gain of $70 million, $59 million of which is subject to refund to customers; thus, the net curtailment gain recognition was $11 million.

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Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES:

The Company is exposed to certain risks in its ongoing business operations.  The primary risk managed by using derivative instruments is interest rate risk.  Interest rate swaps and treasury rate locks are the principal derivative instruments used by the Company to manage interest rate risk associated with its long-term borrowings, although other interest rate derivative contracts may also be used from time to time.  The Company recognizes all derivative assets and liabilities at fair value on the condensed consolidated balance sheets.

Interest Rate Contracts. The Company may enter into interest rate swaps to manage its exposure to changes in interest payments on long-term debt attributable to movements in market interest rates, and may enter into treasury rate locks to manage its exposure to changes in future interest payments attributable to changes in treasury rates prior to the issuance of new long-term debt instruments.

Treasury Rate Locks.  As of March 31, 2013, the Company had no outstanding treasury rate locks.  However, certain of its treasury rate locks that settled in prior periods were associated with interest payments on outstanding long-term debt.  During the predecessor periods, these treasury rate locks were accounted for as cash flow hedges, with the effective portion of their settled value recorded in accumulated other comprehensive income and reclassified into interest expense in the same periods during which the related interest payments on long-term debt impact earnings.

The Company had no derivative instruments at March 31, 2013 and December 31, 2012.

The following tables summarize the location and amount (excluding income tax effects) of derivative instrument gains and losses reported in the Company’s consolidated financial statements for the periods presented:

	Successor				Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012		Period from January 1, 2012 to March 25, 2012
Cash Flow Hedges:
Reclassification of unrealized loss from accumulated other comprehensive income – increase of interest expense	$	—	$	—	$	4

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Debt Obligations

3 Months Ended

Mar. 31, 2013

Debt Disclosure [Abstract]

Debt Obligations

DEBT OBLIGATIONS:

The Company has $250 million principal amount of senior notes which mature within the next twelve months. The Company currently expects to refinance all or a portion of the debt upon maturity or, alternatively, to retire all or a portion of the debt with proceeds from repayment of the note receivable from Southern Union, which funds are available to the Company on a demand basis.

Based on the estimated borrowing rates currently available to the Company and its subsidiaries for loans with similar terms and average maturities, the aggregate fair value of the Company’s consolidated debt obligations at March 31, 2013 and December 31, 2012 was $1.81 billion and $1.81 billion, respectively. As of March 31, 2013 and December 31, 2012, the aggregate carrying amount of the Company’s consolidated debt obligations was $1.75 billion and $1.76 billion, respectively. The fair value of the Company’s consolidated debt obligations is a Level 2 valuation based on the observable inputs used for similar liabilities.

Term Loans.  The effective interest rate for the LNG Holdings term loan due February 2015 was 1.83% at March 31, 2013.

Other.  The Company's notes are subject to certain requirements, such as the maintenance of a fixed charge coverage ratio and a leverage ratio, which if not maintained, restrict the ability of the Company to make certain payments and impose limitations on the ability of the Company to subject its property to liens.  Other covenants impose limitations on restricted payments, including dividends and loans to affiliates, and additional indebtedness. As of March 31, 2013, the Company is in compliance with these covenants.

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Benefits

3 Months Ended

Mar. 31, 2013

Postemployment Benefits [Abstract]

Benefits

BENEFITS:

Components of Net Periodic Benefit Cost

The following tables set forth the components of net periodic benefit cost of the Company’s OPEB plans for the periods presented:

	Successor						Predecessor
	Three Months Ended March 31, 2013			Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Service cost	$	—		$	—		$	1
Interest cost	—			—			1
Expected return on plan assets	(1		)	—			(1		)
Prior service credit amortization	—			—			(1		)
Curtailment recognition (1)	—			(11		)	—
Net periodic benefit cost	$	(1	)	$	(11	)	$	—

⁽¹⁾  Subsequent to the ETE Merger, the Company amended certain of its OPEB plans to prospectively restrict participation in the plans for certain active employees.  The plan amendments resulted in the plans becoming currently over-funded and, accordingly, the Company recorded a gross pre-tax curtailment gain of $70 million, $59 million of which is subject to refund to customers; thus, the net curtailment gain recognition was $11 million.

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Fair Value Measurement

3 Months Ended

Mar. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value Measurement

FAIR VALUE MEASUREMENT:

The Company did not have any assets or liabilities that are measured at fair value on a recurring basis at March 31, 2013. The Company did not have any Level 3 instruments measured at fair value using significant unobservable inputs at March 31, 2013 or December 31, 2012 and there were no transfers between hierarchy levels.

The approximate fair value of the Company’s cash and cash equivalents, accounts receivable and accounts payable is equal to book value, due to their short-term nature.

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2013

Commitments and Contingencies [Abstract]

Environmental Liabilities Table

The table below reflects the amount of accrued liabilities recorded on the condensed consolidated balance sheets at the dates indicated to cover environmental remediation actions where management believes a loss is probable and reasonably estimable.  The Company does not have any material environmental remediation matters assessed as reasonably possible.

	March 31, 2013		December 31, 2012
Current	$	1	$	1
Non-current	5		5
Total environmental liabilities	$	6	$	6

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Benefits - Components of Net Periodic Benefit Cost (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended		3 Months Ended
	Mar. 31, 2012 Successor		Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
Defined Benefit Plan Disclosure
Service cost	$ 0		$ 0	$ 1
Interest cost	0		0	1
Expected return on plan assets	0		(1)	(1)
Prior service credit amortization	0		0	(1)
Curtailment recognition (1)	(11)	[1]	0	0
Net periodic benefit cost	(11)		(1)	0
Pretax curtailment gain	70
Noncurrent refund liability	$ 59

[1] Subsequent to the ETE Merger, the Company amended certain of its OPEB plans to prospectively restrict participation in the plans for certain active employees. The plan amendments resulted in the plans becoming currently over-funded and, accordingly, the Company recorded a gross pre-tax curtailment gain of $70 million, $59 million of which is subject to refund to customers; thus, the net curtailment gain recognition was $11 million.

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CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL (USD $) In Millions	Total	Partners’ Capital	Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Income (Loss) [Member]	Additional Paid-in Capital
Balance, at Dec. 31, 2012	$ 4,041	$ 4,050	$ (9)
Net income	42	42	0
Other	(1)			0	1
Balance, at Mar. 31, 2013	$ 4,082	$ 4,091	$ (9)

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Related Party Transactions

3 Months Ended

Mar. 31, 2013

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS:

Accounts receivable from related companies reflected on the condensed consolidated balance sheets primarily related to services provided for Southern Union, ETE, ETP, and other affiliates. Accounts payable to related companies reflected on the condensed consolidated balance sheets primarily related to payroll funding and overhead allocation provided by ETE, ETP and other affiliates.

Pursuant to a demand note with Southern Union under a cash management program, the Company loans excess cash, net of repayments, to Southern Union.  The Company is credited with interest on the note at a one month LIBOR rate.  Given the uncertainties regarding the timing of the Company’s cash flows, including financings, capital expenditures and operating cash flows, the Company has reported the note receivable as a non-current asset.  The Company has access to the funds via the demand note and expects repayment to ultimately occur to primarily fund capital expenditures or debt retirements.

The following tables provide a summary of related party transactions for the periods presented:

	Successor					Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012			Period from January 1, 2012 to March 25, 2012
Transportation and storage of natural gas	$	3	$	—		$	1
Operation and maintenance and general	16		39		(1)	14
Interest Income	1		—			2

⁽¹⁾  Primarily represents corporate charges for employee expenses related to the merger with ETE offset by expenses attributable to services provided by Panhandle on behalf of affiliated companies.

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Derivative Instrument and Hedging Activities (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended
	Mar. 31, 2012 Successor	Mar. 31, 2013 Successor	Mar. 25, 2012 Predecessor
Derivative
Reclassification of unrealized loss from accumulated other comprehensive income – increase of interest expense	$ 0	$ 0	$ 4

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Derivative Instrument and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives Effect On Income Table

The following tables summarize the location and amount (excluding income tax effects) of derivative instrument gains and losses reported in the Company’s consolidated financial statements for the periods presented:

	Successor				Predecessor
	Three Months Ended March 31, 2013		Period from Acquisition (March 26, 2012) to March 31, 2012		Period from January 1, 2012 to March 25, 2012
Cash Flow Hedges:
Reclassification of unrealized loss from accumulated other comprehensive income – increase of interest expense	$	—	$	—	$	4