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Document And Entity Information	9 Months Ended
Document And Entity Information	Sep. 30, 2014 shares
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	Sep. 30, 2014
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q3
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
CURRENT ASSETS:
Cash and cash equivalents	$ 55	$ 17
Accounts receivable, net	51	69
Accounts receivable from related companies	30	64
Exchanges receivable	17	19
System natural gas and operating supplies	115	203
Other current assets	48	18
Total current assets	316	390
PROPERTY, PLANT AND EQUIPMENT:
Plant in service	3,320	4,208
Construction work in progress	40	70
Total property, plant and equipment	3,360	4,278
Accumulated depreciation and amortization	(243)	(216)
Net property, plant and equipment	3,117	4,062
INVESTMENTS IN UNCONSOLIDATED AFFILIATES	1,480	1,525
GOODWILL	1,152	1,336
NOTE RECEIVABLE FROM RELATED PARTY	386	396
OTHER NON-CURRENT ASSETS, net	106	147
Total assets	6,557	7,856
CURRENT LIABILITIES:
Current maturities of long-term debt	1	1
Accounts payable and accrued liabilities	4	33
Accounts payable to related companies	462	181
Exchanges payable	117	207
Accrued interest	24	12
Price risk management liabilities	4	10
Customer advances and deposits	13	17
Other current liabilities	62	52
Total current liabilities	687	513
LONG-TERM DEBT, less current maturities	1,195	1,246
NOTE PAYABLE TO RELATED PARTY	0	1,090
NON-CURRENT PRICE RISK MANAGEMENT LIABILITIES	9	15
DEFERRED INCOME TAXES	1,452	1,659
OTHER NON-CURRENT LIABILITIES	287	265
COMMITMENTS AND CONTINGENCIES (Note 11)
PARTNERS’ CAPITAL:
Partners’ capital	2,925	3,551
Accumulated other comprehensive income	2	3
Total partners’ capital	2,927	3,554
NONCONTROLLING INTEREST	0	(486)
Total liabilities and partners’ capital	$ 6,557	$ 7,856

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
OPERATING REVENUES:
Transportation and storage of natural gas	$ 125	$ 123	$ 417	$ 442
LNG terminalling	0	55	0	162
NGL sales	0	0	0	249
Other	7	4	22	38
Total operating revenues	132	182	439	891
OPERATING EXPENSES:
Cost of natural gas and other energy	1	1	4	226
Operating, maintenance and general	67	73	184	281
Depreciation and amortization	33	41	96	147
Total operating expenses	101	115	284	654
OPERATING INCOME	31	67	155	237
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(15)	(39)	(52)	(84)
Equity in earnings (losses) from unconsolidated investments	9	9	7	15
Interest income - affiliates	5	3	17	3
Other, net	1	0	5	(1)
Total other expenses, net	0	(27)	(23)	(67)
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE	31	40	132	170
Income tax expense	8	(5)	128	80
IINCOME FROM CONTINUING OPERATIONS	23	45	4	90
Income from discontinued operations	0	13	0	44
NET INCOME	23	58	4	134
NET INCOME (LOSS) ATTRIBUTABLE TO NONCONTROLLING INTEREST	0	21	6	(14)
NET INCOME ATTRIBUTABLE TO PARTNERS	$ 23	$ 37	$ (2)	$ 148

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Income and Comprehensive Income
Net income	$ 23	$ 58	$ 4	$ 134
Other comprehensive income (loss), net of tax:
Change in fair value of commodity hedges	0	0	0	(3)
Actuarial gain (loss) relating to postretirement benefits	0	8	(1)	10
Total other comprehensive income, net of tax	0	8	(1)	7
Comprehensive income	$ 23	$ 66	$ 3	$ 141

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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+ Details

CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL - USD ($) $ in Millions	Total	Trunkline LNG Transaction [Member]	Panhandle Merger [Member]	Limited partner	Limited partner Trunkline LNG Transaction [Member]	Limited partner Panhandle Merger [Member]	Noncontrolling Interest [Member]	Noncontrolling Interest [Member] Trunkline LNG Transaction [Member]	Noncontrolling Interest [Member] Panhandle Merger [Member]	Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss Trunkline LNG Transaction [Member]	Accumulated Other Comprehensive Loss Panhandle Merger [Member]
Stockholders' Equity, Balance	$ 3,068			$ 3,551			$ (486)			$ 3
Distribution to partners	(102)			(102)			0			0
Stockholders' Equity, Other		$ (43)	$ 0		$ (20)	$ (502)		$ (23)	$ 503		$ 0	$ (1)
Net income (loss)	4			(2)			6			0
Stockholders' Equity, Balance	$ 2,927			$ 2,925			$ 0			$ 2

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References

+ Details

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ 4	$ 134
Reconciliation of net income to net cash provided by operating activities:
Depreciation and amortization	96	147
Deferred income taxes	(238)	99
Provision for bad debts	0	7
Amortization included in interest expense	(16)	(25)
Unrealized (gain) loss on derivatives	(12)	(27)
Non-cash compensation expense	4	5
Equity in (earnings) loss of unconsolidated affiliates	(7)	(15)
Distributions from unconsolidated affiliates	18	15
Other non-cash	(5)	10
Changes in operating assets and liabilities, net of merger impacts	336	17
Net cash flows provided by operating activities	180	367
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from SUGS Contribution	0	463
Proceeds from sale of MGE assets, net of transaction costs	0	973
Capital expenditures	(70)	(200)
Distributions from unconsolidated affiliates In excess of cumulative earnings	36	21
Other	(6)	3
Net cash flows provided by (used in) investing activities	(40)	1,260
CASH FLOWS FROM FINANCING ACTIVITIES:
Distribution to partners	(102)	(313)
Issuance of loans from affiliates	0	1,669
Repayments of loans from affiliates	0	(975)
Repayments of Long-term Debt	0	(1,795)
Net change in revolving credit facilities	0	(210)
Other	0	(8)
Net cash flows used in financing activities	(102)	(1,632)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	38	(5)
CASH AND CASH EQUIVALENTS, beginning of period	17	49
CASH AND CASH EQUIVALENTS, end of period	$ 55	$ 44

Operations and Organization (Notes)

9 Months Ended

Sep. 30, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Operations and Organization

OPERATIONS AND ORGANIZATION:

Business Operations

Panhandle Eastern Pipe Line Company, LP and its subsidiaries (collectively, “we,” “us,” the “Company” or “Panhandle”) are primarily engaged in the interstate transportation and storage of natural gas and are subject to the rules and regulations of the FERC. The Company’s entities include the following:


•	PEPL, an indirect wholly-owned subsidiary of ETP;


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


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


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

The Company’s operations currently 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 owning underground storage capacity.

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

See Note 2 for information related to the Panhandle Merger. We have accounted for this transaction as a reorganization of entities under common control; therefore, the consolidated financial statements of the Company were retrospectively adjusted to consolidate Southern Union for all periods. As a result of this retrospective consolidation, the Company’s consolidated results of operations for the three and nine months ended September 30, 2013 include Southern Union’s former natural gas gathering and processing operations, which were contributed to an affiliate in 2013 as discussed in Note 2, and Southern Union’s former local distribution operations, which were sold in 2013 and were presented as discontinued operations as discussed in Note 2.

Our former consolidated subsidiary, Trunkline LNG Company, LLC, changed its name in September 2014 to Lake Charles LNG Company, LLC. All references to this company throughout this document reflects the new name of the company, regardless of whether the disclosure relates to periods or events prior to the dates of the name change.

Preparation of Interim Financial Statements

The accompanying consolidated balance sheet as of December 31, 2013 has been prepared on the same basis as the audited financial statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The accompanying unaudited interim consolidated financial statements and notes thereto of the Company as of September 30, 2014 and for the three and nine months ended September 30, 2014 and 2013 have been prepared in accordance with GAAP for interim consolidated financial information and pursuant to the rules and regulations of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete consolidated financial statements. However, management believes that the disclosures made are adequate to make the information not misleading. The results of operations for interim periods are not necessarily indicative of the results to be expected for a full year due to the seasonal nature of the Company’s operations.

In the opinion of management, all adjustments (all of which are normal and recurring) have been made that are necessary to fairly state the consolidated financial position of the Company as of September 30, 2014, and the Company’s results of operations and cash flows for the three and nine months ended September 30, 2014 and 2013. The unaudited interim consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto presented in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, as filed with the SEC on February 27, 2014.

Certain prior period amounts have been reclassified to conform to the 2014 presentation. These reclassifications had no impact on net income or total equity.

New Accounting Pronouncements

In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. The Company is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies.

In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (“ASU 2014-08”), which changed the requirements for reporting discontinued operations. Under ASU 2014-08, a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. ASU 2014-08 is effective for all disposals or classifications as held for sale of components of an entity that occur within fiscal years beginning after December 15, 2014, and early adoption is permitted. We expect to adopt this standard for the year ending December 31, 2015. ASU 2014-08 could have an impact on whether transactions will be reported in discontinued operations in the future, as well as the disclosures required when a component of an entity is disposed.

Mergers, Deconsolidations and Related Transactions (Notes)	9 Months Ended
	Sep. 30, 2014
Business Combinations [Abstract]
Mergers and Deconsolidations	MERGERS, DECONSOLIDATIONS AND RELATED TRANSACTIONS: 2014 Transactions Panhandle Merger On January 10, 2014, the Company consummated a merger with Southern Union, the indirect parent of the Company, and PEPL Holdings, the sole limited partner of the Company, pursuant to which each of Southern Union and PEPL Holdings, a wholly-owned subsidiary of Southern Union, were merged with and into the Company (the “Panhandle Merger”), with the Company surviving the Panhandle Merger. In connection with the Panhandle Merger, the Company assumed Southern Union’s obligations under its 7.6% Senior Notes due 2024, 8.25% Senior Notes due 2029 and Floating Rate Junior Subordinated Notes due 2066. At the time of the Panhandle Merger, Southern Union did not have material operations of its own, other than its ownership of the Company and noncontrolling interests in PEI Power II, LLC, Regency (31.4 million common units and 6.3 million Class F Units) and ETP (2.2 million common units). In connection with the Panhandle Merger, the Company also assumed PEPL Holdings’ guarantee of $600 million of Regency senior notes. Lake Charles LNG Transaction On February 19, 2014, Panhandle transferred to ETP all of the interests in Lake Charles LNG, the entity that owns a LNG regasification facility in Lake Charles, Louisiana, in exchange for the cancellation of a $1.09 billion note payable to ETP that was assumed by the Company in the merger with Southern Union on January 10, 2014. Also on February 19, 2014, ETE and ETP completed the transfer to ETE of Lake Charles LNG from ETP in exchange for the redemption by ETP of 18.7 million ETP common units held by ETE. The transaction was effective as of January 1, 2014, at which time Panhandle deconsolidated Lake Charles LNG, including goodwill of $184 million and intangible assets of $50 million related to Lake Charles LNG. The results of Lake Charles LNG’s operations have not been presented as discontinued operations and Lake Charles LNG’s assets and liabilities have not been presented as held for sale in the Company’s consolidated financial statements due to continuing involvement among the entities. 2013 Transactions Sale of Southern Union’s Distribution Operations In September 2013, Southern Union completed its sale of the assets of MGE for an aggregate purchase price of $975 million, subject to customary post-closing adjustments. In December 2013, Southern Union completed its sale of the assets of NEG for cash proceeds of $40 million, subject to customary post-closing adjustments, and the assumption of $20 million of debt. MGE and NEG have been classified as discontinued operations in the consolidated statements of operations. SUGS Contribution On April 30, 2013, Southern Union completed its contribution to Regency of all of the issued and outstanding membership interest in Southern Union Gathering Company, LLC, and its subsidiaries, including SUGS (the “SUGS Contribution”). The general partner and IDRs of Regency are owned by ETE. The consideration paid by Regency in connection with this transaction consisted of (i) the issuance of approximately 31.4 million Regency common units to Southern Union, (ii) the issuance of approximately 6.3 million Regency Class F units to Southern Union, (iii) the distribution of $463 million in cash to Southern Union, net of closing adjustments, and (iv) the payment of $30 million in cash to a subsidiary of ETP. This transaction was between commonly controlled entities; therefore, the amounts recorded in the consolidated balance sheet for the investment in Regency and the related deferred tax liabilities were based on the historical book value of SUGS. In addition, PEPL Holdings provided a guarantee of collection with respect to the payment of the principal amounts of Regency’s debt related to the SUGS Contribution. The Regency Class F units have the same rights, terms and conditions as the Regency common units, except that the Company, as successor to Southern Union, will not receive distributions on the Regency Class F units for the first eight consecutive quarters following the closing, and the Regency Class F units will thereafter automatically convert into Regency common units on a one-for-one basis.

- Definition

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

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+ Details

Related Party Transactions (Notes)

9 Months Ended

Sep. 30, 2014

Related Party Transactions

RELATED PARTY TRANSACTIONS:

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

The following table provides a summary of the related party activity included in our consolidated statements of operations:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Operating revenues	$	4	$	5	$	28	$	34
Cost of natural gas and other energy	—		—		—		16
Operating, maintenance and general	13		16		37		59
Interest expense, net of interest capitalized	—		14		—		15
Interest income — affiliates	5		3		17		3
Equity in earnings of unconsolidated investments	9		9		7		15

The Company received $6 million and $6 million in distributions related to its investment in ETP during the nine months ended September 30, 2014 and 2013, respectively. The Company also received $45 million and $29 million in distributions related to its investment in Regency during the nine months ended September 30, 2014 and 2013, respectively.

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References + Details

INVESTMENTS IN UNCONSOLIDATED AFFILIATES INVESTMENTS IN UNCONSOLIDATED AFFILATES (Notes)

9 Months Ended

Sep. 30, 2014

Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures [Abstract]

Equity Method Investments and Joint Ventures Disclosure [Text Block]

INVESTMENTS IN UNCONSOLIDATED AFFILIATES:

The Company’s investment in Regency is reflected in our consolidated financial statements using the equity method. This investment consists of approximately 31.4 million Regency common units and approximately 6.3 million Regency Class F units that were issued to Southern Union as consideration for the SUGS Contribution.

The following table presents aggregated selected income statement data for Regency (on a 100% basis for all periods presented).



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Revenue	$	1,483	$	665	$	3,524	$	1,844
Operating income	144		24		201		43
Net income	107		42		115		24

In addition to the equity method investment described above, we have other equity method investments which were not individually significant to our consolidated financial statements.

Comprehensive Income (Notes)	9 Months Ended
Comprehensive Income (Notes)	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Comprehensive Income	ACCUMULATED OTHER COMPREHENSIVE INCOME: As of September 30, 2014 and December 31, 2013, accumulated other comprehensive income consisted of net actuarial gains and prior service costs related to our OPEB plans.

- Definition

The entire disclosure for comprehensive income, which includes, but is not limited to, 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income.

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-Glossary Reclassification Adjustments
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+ Details

Debt Obligations (Notes)	9 Months Ended
Debt Obligations (Notes)	Sep. 30, 2014
Debt Disclosure [Abstract]
Debt Obligations	DEBT OBLIGATIONS: 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 September 30, 2014 and December 31, 2013 was $1.26 billion and $2.38 billion, respectively. As of September 30, 2014 and December 31, 2013, the aggregate carrying amount of the Company’s consolidated debt obligations was $1.20 billion and $2.34 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. Assumption of Southern Union Debt In connection with the consummation of the Panhandle Merger, Panhandle assumed Southern Union’s long-term debt obligations. As of September 30, 2014, the long-term debt assumed in the Panhandle Merger consisted of $83 million in aggregate principal amount of 7.6% Senior Notes due 2024, $33 million in aggregate principal amount of 8.25% Senior Notes due 2029 and $54 million in aggregate principal amount of Floating Rate Junior Subordinated Notes due 2066. The amounts recorded in the consolidated balance sheet also reflected unamortized fair value adjustments, which were $13 million in the aggregate at September 30, 2014. In connection with the Lake Charles LNG Transaction, the $1.09 billion note payable to ETP that was assumed by the Company in the merger with Southern Union on January 10, 2014 was canceled. Compliance With Our Covenants 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 September 30, 2014, the Company was in compliance with these covenants.

Retirement Benefits (Notes)

9 Months Ended

Sep. 30, 2014

Postemployment Benefits [Abstract]

Benefits

RETIREMENT BENEFITS:

Components of Net Periodic Benefit Cost

The following tables set forth the components of net periodic benefit cost of the Company’s pension and OPEB plans:



	Pension Benefits					Other Postretirement Benefits
	Three Months Ended September 30,					Three Months Ended September 30,
	2014		2013			2014			2013
Net Periodic Benefit Cost:
Service cost	$	—	$	—		$	—		$	(1	)
Interest cost	—		2			—			1
Expected return on plan assets	—		(3		)	(1		)	(2		)
Prior service credit amortization	—		—			—			1
Actuarial loss amortization	—		1			—			—
	—		—			(1		)	(1		)
Regulatory adjustment⁽¹⁾	—		1			—			—
Net periodic benefit cost	$	—	$	1		$	(1	)	$	(1	)



	Pension Benefits					Other Postretirement Benefits
	Nine Months Ended September 30,					Nine Months Ended September 30,
	2014		2013			2014			2013
Net Periodic Benefit Cost:
Service cost	$	—	$	3		$	—		$	—
Interest cost	—		6			1			2
Expected return on plan assets	—		(9		)	(4		)	(5		)
Prior service credit amortization	—		—			—			1
Actuarial loss amortization	—		2			—			—
	—		2			(3		)	(2		)
Regulatory adjustment⁽¹⁾	—		5			—			—
Net periodic benefit cost	$	—	$	7		$	(3	)	$	(2	)

⁽¹⁾

The Company has historically recovered certain qualified pension benefit plan and other postretirement benefit plan costs through rates charged to utility customers. Certain utility commissions require that the recovery of these costs be based on the Employee Retirement Income Security Act of 1974, as amended, or other utility commission specific guidelines. The difference between these regulatory-based amounts and the periodic benefit cost calculated pursuant to GAAP is deferred as a regulatory asset or liability and amortized to expense over periods in which this difference will be recovered in rates, as promulgated by the applicable utility commission.

The Company no longer has pension plans after the sale of the assets of MGE and NEG in 2013.

INCOME TAXES Income Taxes (Notes)	9 Months Ended
INCOME TAXES Income Taxes (Notes)	Sep. 30, 2014
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	INCOME TAXES: The increase in the effective tax rate for the nine months ended September 30, 2014 was primarily due to the Lake Charles LNG Transaction (see Note 2). The Lake Charles LNG Transaction, which was treated as a sale for tax purposes, resulted in $81 million of incremental income tax expense. For the three months ended September 30, 2014, the statutory rate differed from the effective rate primarily due to state income tax adjustments. For the three and nine months ended September 30, 2013, the effective tax rate exceeded the statutory rate primarily due to state income taxes resulting from the SUGS Contribution and other internal restructuring activities.

Derivative Instruments and Hedging Activities (Notes)

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Price Risk Management Assets and Liabilities

PRICE RISK MANAGMENT ASSETS AND LIABILITIES:

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. Southern Union was also previously exposed to commodity price risk in its gathering and processing and distribution operations. Natural gas price swaps were the principal derivative instruments used by Southern Union to manage commodity price risk associated with purchases and/or sales of natural gas, although other commodity derivative contracts were used from time to time. The Company recognizes all derivative assets and liabilities at fair value on the 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.

The Company has outstanding interest rate swap agreements to hedge floating rate notes with an aggregate notional amount of $125 million, all of which are for ten-year periods. The Company settled $50 million of five-year swaps during the third quarter of 2013, $175 million of ten-year swaps during the fourth quarter of 2013, $25 million of five-year swaps during the fourth quarter of 2013 and $150 million of ten-year swaps during the third quarter of 2014. These interest rate swaps became effective on November 1, 2011. The Company pays interest on the floating rate notes based on three-month LIBOR plus a credit spread of 3.0175% beginning November 1, 2011. The interest rate swaps effectively fix the floating rate LIBOR-based portion of the interest payments on the swapped notes to a weighted average fixed rate of 3.820%.

Credit Risk

Credit risk refers to the risk that a shipper may default on its contractual obligations resulting in a credit loss to the Company. A credit policy has been approved and implemented to govern the Company’s portfolio of shippers with the objective of mitigating credit losses. This policy establishes guidelines, controls, and limits, consistent with FERC filed tariffs, to manage credit risk within approved tolerances by mandating an appropriate evaluation of the financial condition of existing and potential shippers, monitoring agency credit ratings, and by implementing credit practices that limit credit exposure according to the risk profiles of the shippers. Furthermore, the Company may, at times, require collateral under certain circumstances in order to mitigate credit risk as necessary.

The Company’s shippers consist of a diverse portfolio of customers across the energy industry, including oil and gas producers, midstream companies, municipalities, utilities, and commercial and industrial end users. Our overall exposure may be affected positively or negatively by macroeconomic or regulatory changes that could impact our shippers to one extent or another. Currently, management does not anticipate a material adverse effect in our financial position or results of operations as a consequence of shipper non-performance.

Summary Financial Statement Information

The consolidated balance sheets as of September 30, 2014 and December 31, 2013 included price risk management liabilities, all of which related to interest rate contracts that are not designated as hedging instruments and are recorded at fair value.

The following table summarizes the location and amount (excluding income tax effects) of derivative instrument gains and losses reported in the Company’s consolidated financial statements:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Cash Flow Hedges:
Commodity contracts — Gathering and Processing:
Change in fair value — decrease in accumulated other comprehensive income	$	—		$	—		$	—		$	(3	)
Economic Hedges:
Interest rate contracts:
Change in fair value — increase (decrease) in interest expense	(13		)	1			(6		)	(27		)
Commodity contracts:
Change in fair value — decrease in deferred natural gas purchases	—			(4		)	—			(7		)

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

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+ Details

FAIR VALUE Fair Value (Notes)

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value Disclosures [Text Block]

FAIR VALUE MEASUREMENT:

The following table sets forth the Company’s assets and liabilities that are measured at fair value on a recurring basis:



	Fair Value as of		Fair Value Measurements at September 30, 2014 Using Fair Value Hierarchy
	September 30, 2014		Level 1		Level 2
Assets:
Total	$	—	$	—	$	—
Liabilities:
Interest rate swaps	$	13	$	—	$	13
Total	$	13	$	—	$	13

The Company’s interest rate swap derivatives are valued using pricing models based on an income approach that discounts future cash flows to a present value amount. The significant pricing model inputs for interest rate swaps include published rates for U.S. Dollar LIBOR interest rate swaps. The pricing models also adjust for nonperformance risk associated with the counterparty or Company, as applicable, through the use of credit risk adjusted discount rates based on published default rates. During the period ended September 30, 2014, no transfers were made between any levels within the fair value hierarchy.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Commitments and Contingencies

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies [Abstract]

Commitments and Contingencies Disclosure

REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES:

Sea Robin Rate Case

On December 2, 2013, Sea Robin filed a general NGA Section 4 rate case at the FERC as required by a previous rate case settlement. In the filing, Sea Robin seeks to increase its authorized rates to recover costs related to asset retirement obligations, depreciation, and return and taxes. A settlement was reached with the shippers and a stipulation and agreement was filed with the FERC on July 23, 2014. The settlement was certified to the FERC by the administrative law judge on October 7, 2014 and is pending approval by the FERC.

PEPL Holdings Guarantee of Collection

In connection with the SUGS Contribution, Regency issued $600 million of 4.50% Senior Notes due 2023 (the “Regency Debt”), the proceeds of which were used by Regency to fund the cash portion of the consideration, as adjusted, and pay certain other expenses or disbursements directly related to the closing of the SUGS Contribution. Pursuant to an agreement between Regency and PEPL Holdings, PEPL Holdings provided a guarantee of collection (on a nonrecourse basis to Southern Union) to Regency and Regency Energy Finance Corp. with respect to the payment of the principal amount of the Regency Debt through maturity in 2023. In connection with the completion of the Panhandle Merger, in which PEPL Holdings was merged with and into Panhandle, the guarantee of collection for the Regency Debt was assumed by Panhandle.

Contingent Residual Support Agreement with ETP

In connection with the Panhandle Merger, the Company assumed Southern Union’s obligations under a contingent residual support agreement with ETP and Citrus ETP Finance LLC, pursuant to which the Company provides contingent, residual support to Citrus ETP Finance LLC (on a non-recourse basis to the Company) with respect to Citrus ETP Finance LLC’s obligations to ETP to support the payment of $2.0 billion in principal amount of senior notes issued by ETP on January 17, 2012.

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 consolidated balance sheets at the dates indicated to cover environmental remediation activities where management believes a loss is probable and reasonably estimable. The Company is not able to estimate the possible loss or range of loss in excess of amounts accrued. The Company does not have any material environmental remediation matters assessed as reasonably possible.



	September 30, 2014		December 31, 2013
Current	$	1	$	2
Non-current	3		3
Total environmental liabilities	$	4	$	5

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.

Attorney General of the Commonwealth of Massachusetts v New England Gas Company. On July 7, 2011, the Massachusetts Attorney General (“AG”) filed a regulatory complaint with the Massachusetts Department of Public Utilities (“MDPU”) against New England Gas Company with respect to certain environmental cost recoveries. The AG is seeking a refund to New England Gas Company customers for alleged “excessive and imprudently incurred costs” related to legal fees associated with Southern Union’s environmental response activities. In the complaint, the AG requests that the MDPU initiate an investigation into the New England Gas Company’s collection and reconciliation of recoverable environmental costs including: (i) the prudence of any and all legal fees, totaling $19 million, that were charged by the Kasowitz, Benson, Torres & Friedman firm and passed through the recovery mechanism since 2005, the year when a partner in the firm, Southern Union’s former Vice Chairman, President and Chief Operating Officer, joined Southern Union’s management team; (ii) the prudence of any and all legal fees that were charged by the Bishop, London & Dodds firm and passed through the recovery mechanism since 2005, the period during which a member of the firm served as Southern Union’s Chief Ethics Officer; and (iii) the propriety and allocation of certain legal fees charged that were passed through the recovery mechanism that the AG contends only qualify for a lesser, 50%, level of recovery. Southern Union has filed its answer denying the allegations and moved to dismiss the complaint, in part on a theory of collateral estoppel. The hearing officer has deferred consideration of Southern Union’s motion to dismiss. The AG’s motion to be reimbursed expert and consultant costs by Southern Union of up to $150,000 was granted. By tariff, these costs are recoverable through rates charged to New England Gas Company customers. The hearing officer previously stayed discovery pending resolution of a dispute concerning the applicability of attorney-client privilege to legal billing invoices. The MDPU issued an interlocutory order on June 24, 2013 that lifted the stay, and discovery has resumed. The Company (as successor to Southern Union) believes it has complied with all applicable requirements regarding its filings for cost recovery and has not recorded any accrued liability; however, the Company will continue to assess its potential exposure for such cost recoveries as the matter progresses.

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 September 30, 2014 and December 31, 2013, the Company recorded litigation and other claim-related accrued liabilities of $24 million and $24 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.

Other Commitments and Contingencies

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.

OPERATIONS AND ORGANIZATION OPERATIONS AND ORGANIZATION (Policies) (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption not permitted. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. The Company is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies. In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (“ASU 2014-08”), which changed the requirements for reporting discontinued operations. Under ASU 2014-08, a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. ASU 2014-08 is effective for all disposals or classifications as held for sale of components of an entity that occur within fiscal years beginning after December 15, 2014, and early adoption is permitted. We expect to adopt this standard for the year ending December 31, 2015. ASU 2014-08 could have an impact on whether transactions will be reported in discontinued operations in the future, as well as the disclosures required when a component of an entity is disposed.

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2014

The following table provides a summary of the related party activity included in our consolidated statements of operations:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Operating revenues	$	4	$	5	$	28	$	34
Cost of natural gas and other energy	—		—		—		16
Operating, maintenance and general	13		16		37		59
Interest expense, net of interest capitalized	—		14		—		15
Interest income — affiliates	5		3		17		3
Equity in earnings of unconsolidated investments	9		9		7		15

INVESTMENTS IN UNCONSOLIDATED AFFILIATES INVESTMENTS IN UNCONSOLIDATED AFFILIATES (Tables)

9 Months Ended

Sep. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

Investments in and Advances to Affiliates [Table Text Block]

The following table presents aggregated selected income statement data for Regency (on a 100% basis for all periods presented).



	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013
Revenue	$	1,483	$	665	$	3,524	$	1,844
Operating income	144		24		201		43
Net income	107		42		115		24

Retirement Benefits (Tables)

9 Months Ended

Sep. 30, 2014

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 pension and OPEB plans:



	Pension Benefits					Other Postretirement Benefits
	Three Months Ended September 30,					Three Months Ended September 30,
	2014		2013			2014			2013
Net Periodic Benefit Cost:
Service cost	$	—	$	—		$	—		$	(1	)
Interest cost	—		2			—			1
Expected return on plan assets	—		(3		)	(1		)	(2		)
Prior service credit amortization	—		—			—			1
Actuarial loss amortization	—		1			—			—
	—		—			(1		)	(1		)
Regulatory adjustment⁽¹⁾	—		1			—			—
Net periodic benefit cost	$	—	$	1		$	(1	)	$	(1	)



	Pension Benefits					Other Postretirement Benefits
	Nine Months Ended September 30,					Nine Months Ended September 30,
	2014		2013			2014			2013
Net Periodic Benefit Cost:
Service cost	$	—	$	3		$	—		$	—
Interest cost	—		6			1			2
Expected return on plan assets	—		(9		)	(4		)	(5		)
Prior service credit amortization	—		—			—			1
Actuarial loss amortization	—		2			—			—
	—		2			(3		)	(2		)
Regulatory adjustment⁽¹⁾	—		5			—			—
Net periodic benefit cost	$	—	$	7		$	(3	)	$	(2	)

⁽¹⁾

PRICE RISK MANAGEMENT ASSETS AND LIABILITIES Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments, Gain (Loss) [Table Text Block]

The following table summarizes the location and amount (excluding income tax effects) of derivative instrument gains and losses reported in the Company’s consolidated financial statements:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
Cash Flow Hedges:
Commodity contracts — Gathering and Processing:
Change in fair value — decrease in accumulated other comprehensive income	$	—		$	—		$	—		$	(3	)
Economic Hedges:
Interest rate contracts:
Change in fair value — increase (decrease) in interest expense	(13		)	1			(6		)	(27		)
Commodity contracts:
Change in fair value — decrease in deferred natural gas purchases	—			(4		)	—			(7		)

FAIR VALUE Fair Value (Tables)

9 Months Ended

Sep. 30, 2014

Fair Value [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]

The following table sets forth the Company’s assets and liabilities that are measured at fair value on a recurring basis:



	Fair Value as of		Fair Value Measurements at September 30, 2014 Using Fair Value Hierarchy
	September 30, 2014		Level 1		Level 2
Assets:
Total	$	—	$	—	$	—
Liabilities:
Interest rate swaps	$	13	$	—	$	13
Total	$	13	$	—	$	13

Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies [Abstract]

Environmental Liabilities Table



	September 30, 2014		December 31, 2013
Current	$	1	$	2
Non-current	3		3
Total environmental liabilities	$	4	$	5

Operations and Organizaton (Details) - Panhandle [Member]	9 Months Ended
	Sep. 30, 2014
General partnership
Description of the Business
General partnership interest	1.00%
Limited partner
Description of the Business
Limited partnership interest	99.00%

Mergers, Deconsolidations and Related Transactions (Narrative) (Details) - USD ($) shares in Millions, $ in Millions	1 Months Ended			9 Months Ended		12 Months Ended
	Feb. 28, 2014	Dec. 31, 2013	Apr. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Feb. 19, 2014	Jan. 10, 2014
Business Acquisition
NOTE PAYABLE TO RELATED PARTY		$ 1,090		$ 0		$ 1,090
Goodwill		1,336		1,152		1,336
Proceeds from Divestiture of Businesses				$ 0	$ 973
7.60% Senior Notes, due February 1, 2024 [Member]
Business Acquisition
Debt Instrument, Interest Rate, Stated Percentage				7.60%				7.60%
8.25% Senior Notes, due November 14, 2029 [Member]
Business Acquisition
Debt Instrument, Interest Rate, Stated Percentage				8.25%				8.25%
Regency 4.50% Senior Notes Due 2023 [Member]
Business Acquisition
Debt Instrument, Interest Rate, Stated Percentage				4.50%
Guarantor Obligations, Current Carrying Value				$ 600
New England Gas Company [Member]
Business Acquisition
Proceeds from Divestiture of Businesses		40
Noncash or Part Noncash Divestiture, Amount of Consideration Received		$ 20
Missouri Gas Energy [Member]
Business Acquisition
Proceeds from Divestiture of Businesses						$ 975
SUGS Contribution [Member]
Business Acquisition
Business Combination, Consideration Transferred			$ 463
Cash Acquired from Acquisition			$ 30
Trunkline LNG Transaction [Member]
Business Acquisition
Partners' Capital Account, Units, Redeemed	18.7
Goodwill							$ 184
Impairment of Intangible Assets (Excluding Goodwill)							$ 50

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Related Party Transaction
Transportation and storage of natural gas	$ 4	$ 5	$ 28	$ 34
Cost of Natural Gas and Other Energy	0	0	0	16
Operating, maintenance and general	13	16	37	59
Interest Expense, net of interest capitalized	0	14	0	15
Interest income - affiliates	5	3	17	3
Equity in earnings (losses) from unconsolidated investments	$ 9	$ 9	$ 7	$ 15

Related Party (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended
Related Party (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2014	Sep. 30, 2013
Related Party Transaction
Proceeds from Equity Method Investment, Dividends or Distributions	$ 18	$ 15
ETP
Related Party Transaction
Proceeds from Equity Method Investment, Dividends or Distributions	6	6
Regency [Member]
Related Party Transaction
Proceeds from Equity Method Investment, Dividends or Distributions	$ 45	$ 29

INVESTMENTS IN UNCONSOLIDATED AFFILIATES INV IN UNCONSOLIDATED AFF. - Schedule of Equity Method Investments (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Summarized Financial Information, Revenue	$ 1,483	$ 665	$ 3,524	$ 1,844
Equity Method Investment, Summarized Financial Information, Income (Loss) from Continuing Operations before Extraordinary Items	144	24	201	43
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	$ 107	$ 42	$ 115	$ 24
Regency [Member]
Schedule of Equity Method Investments [Line Items]
Number of common units of a subsidiary partnership that are held by a less than wholly-owned subsidiary of the Parent.	31.4		31.4
Class F Units [Member] \| Regency [Member]
Schedule of Equity Method Investments [Line Items]
Number of common units of a subsidiary partnership that are held by a less than wholly-owned subsidiary of the Parent.	6.3		6.3

Debt Obligations - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2014	Feb. 19, 2014	Jan. 10, 2014	Dec. 31, 2013
Debt Instrument
Notes Payable, Related Parties, Noncurrent	$ 0			$ 1,090
Estimate of Fair Value, Fair Value Disclosure
Debt Instrument
Debt Instrument, Fair Value Disclosure	1,260			2,380
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Debt Instrument
Long term debt, amount outstanding	1,200			$ 2,340
Junior Subordinated Debt [Member]
Debt Instrument
Senior Notes, Noncurrent	$ 54
7.60% Senior Notes, due February 1, 2024 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	7.60%		7.60%
Senior Notes, Noncurrent	$ 83
8.25% Senior Notes, due November 14, 2029 [Member]
Debt Instrument
Debt Instrument, Interest Rate, Stated Percentage	8.25%		8.25%
Senior Notes, Noncurrent	$ 33
Southern Union [Member]
Debt Instrument
Unamortized Net Premiums And Fair Value Adjustments	$ 13
ETP
Debt Instrument
Notes Payable, Related Parties, Noncurrent		$ 1,090

Retirement Benefits - Components of Net Periodic Benefit Cost (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Pension Plan, Defined Benefit [Member]

Defined Benefit Plan Disclosure

Service cost

$ 0

$ 3

Interest cost

Expected return on plan assets

(3)

(9)

Prior service credit amortization

Actuarial loss amortization

Net periodic benefit cost subtotal

Regulatory Adjustment

^[1]

Net periodic benefit cost

Other Postretirement Benefit Plan, Defined Benefit [Member]

Defined Benefit Plan Disclosure

Service cost

(1)

Interest cost

Expected return on plan assets

(1)

(2)

(4)

(5)

Prior service credit amortization

Actuarial loss amortization

Net periodic benefit cost subtotal

(1)

(3)

(2)

Regulatory Adjustment

^[1]

Net periodic benefit cost

$ (1)

$ (3)

$ (2)

[1]

INCOME TAXES Income Taxes (Details) $ in Millions	9 Months Ended
INCOME TAXES Income Taxes (Details) $ in Millions	Sep. 30, 2014 USD ($)
Trunkline LNG [Member]
Income Tax Expense (Benefit)	$ 81

PRICE RISK MANAGEMENT ASSETS AND LIABILITIES Derivative Instruments - Income Statement Impact (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Cash Flow Hedging [Member] \| Commodity Contract [Member]
Derivative [Line Items]
Change in fair value - decrease in accumulated other comprehensive income	$ 0	$ 0	$ 0	$ (3)
Fair Value Hedging [Member] \| Interest Rate Contract [Member]
Derivative [Line Items]
Change in fair value - increase (decrease) in interest expense	(13)	1	(6)	(27)
Fair Value Hedging [Member] \| Commodity Contract [Member]
Derivative [Line Items]
Change in fair value - increase (decrease) in deferred natural gas purchases	$ 0	$ (4)	$ 0	$ (7)

PRICE RISK MANAGEMENT ASSETS AND LIABILITIES Derivative Instruments Narrative (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Sep. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Debt Instrument, Basis Spread on Variable Rate				3.0175%
Interest Rate Swap, Ten Year Period [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Notional Amount	$ 125			$ 125
Settlement of Interest Rate Swaps	$ 150	$ 175
Derivative, Average Fixed Interest Rate	3.82%			3.82%
Interest Rate Swap, Five Year Period [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Settlement of Interest Rate Swaps		$ 25	$ 50

FAIR VALUE Fair Value (Details) - Fair Value, Measurements, Recurring [Member] $ in Millions	Sep. 30, 2014 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	$ 0
Interest Rate Derivative Liabilities, at Fair Value	13
Liabilities, Fair Value Disclosure, Recurring	13
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	0
Interest Rate Derivative Liabilities, at Fair Value	0
Liabilities, Fair Value Disclosure, Recurring	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure	0
Interest Rate Derivative Liabilities, at Fair Value	13
Liabilities, Fair Value Disclosure, Recurring	$ 13

Commitments and Contingencies - Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Loss Contingencies
Current	$ 1	$ 2
Non-current	3	3
Total environmental liabilities	$ 4	$ 5

Commitment and Contingenices (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Loss Contingencies
Contingent Residual Support Agreement, Amount	$ 2,000,000,000
Estimated litigation liability	24,000,000	$ 24,000,000
Regency 4.50% Senior Notes Due 2023 [Member]
Loss Contingencies
Guarantor Obligations, Current Carrying Value	$ 600,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%
Attorney General of Commonwealth [Member]
Loss Contingencies
Legal Fees	$ 19,000,000
Percentage Of Recovery	50.00%
Reimbursement expert and consultant cost, maximum	$ 150,000

Label	Element	Value
ETP [Member]
Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.	pepl_NumberofcommonunitsofasubsidiarypartnershipthatareheldbyawhollyownedsubsidiaryoftheParent.	2,200,000