Edgar Filing: Spectra Energy Corp.

SE-2014.06.30 10Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q



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

For the quarterly period ended June 30, 2014



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

For the transition period from to

Commission file number 1-33007

SPECTRA ENERGY CORP

(Exact Name of Registrant as Specified in its Charter)



Delaware		20-5413139
(State or other jurisdiction of incorporation)		(IRS Employer Identification No.)

5400 Westheimer Court

Houston, Texas 77056

(Address of principal executive offices, including zip code)

713-627-5400

(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 ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§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 ý No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of Exchange Act.

Large accelerated filer ý Accelerated filer ¨ Non-accelerated filer ¨ 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 ý

Number of shares of Common Stock, $0.001 par value, outstanding as of June 30, 2014: 670,893,796

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SPECTRA ENERGY CORP

FORM 10-Q FOR THE QUARTER ENDED

June 30, 2014

INDEX



		Page
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)	4
	Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2014 and 2013	4
	Condensed Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2014 and 2013	5
	Condensed Consolidated Balance Sheets as of June 30, 2014 and December 31, 2013	6
	Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2014 and 2013	8
	Condensed Consolidated Statements of Equity for the six months ended June 30, 2014 and 2013	9
	Notes to Condensed Consolidated Financial Statements	10
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	33
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	45
Item 4.	Controls and Procedures	45

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	46
Item 1A.	Risk Factors	46
Item 6.	Exhibits	46
	Signatures	47

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This document includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements represent management’s intentions, plans, expectations, assumptions and beliefs about future events. These forward-looking statements are identified by terms and phrases such as: anticipate, believe, intend, estimate, expect, continue, should, could, may, plan, project, predict, will, potential, forecast, and similar expressions. Forward-looking statements are subject to risks, uncertainties and other factors, many of which are outside our control and could cause actual results to differ materially from the results expressed or implied by those forward-looking statements. Factors used to develop these forward-looking statements and that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:


•	state, provincial, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an effect on rate structure, and affect the speed at and degree to which competition enters the natural gas and oil industries;


•	outcomes of litigation and regulatory investigations, proceedings or inquiries;


•	weather and other natural phenomena, including the economic, operational and other effects of hurricanes and storms;


•	the timing and extent of changes in commodity prices, interest rates and foreign currency exchange rates;


•	general economic conditions, including the risk of a prolonged economic slowdown or decline, or the risk of delay in a recovery, which can affect the long-term demand for natural gas and oil and related services;


•	potential effects arising from terrorist attacks and any consequential or other hostilities;


•	changes in environmental, safety and other laws and regulations;


•	the development of alternative energy resources;


•	results and costs of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general market and economic conditions;


•	increases in the cost of goods and services required to complete capital projects;


•	declines in the market prices of equity and debt securities and resulting funding requirements for defined benefit pension plans;


•	growth in opportunities, including the timing and success of efforts to develop U.S. and Canadian pipeline, storage, gathering, processing and other related infrastructure projects and the effects of competition;


•	the performance of natural gas and oil transmission and storage, distribution, and gathering and processing facilities;


•	the extent of success in connecting natural gas and oil supplies to gathering, processing and transmission systems and in connecting to expanding gas and oil markets;


•	the effects of accounting pronouncements issued periodically by accounting standard-setting bodies;


•	conditions of the capital markets during the periods covered by forward-looking statements; and


•	the ability to successfully complete merger, acquisition or divestiture plans; regulatory or other limitations imposed as a result of a merger, acquisition or divestiture; and the success of the business following a merger, acquisition or divestiture.

In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than Spectra Energy Corp has described. Spectra Energy Corp undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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PART I. FINANCIAL INFORMATION



Item 1.	Financial Statements.

SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In millions, except per-share amounts)



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
Operating Revenues
Transportation, storage and processing of natural gas	$	780	$	766	$	1,667	$	1,566
Distribution of natural gas	309		283		935		908
Sales of natural gas liquids	40		65		227		177
Transportation of crude oil	70		67		141		80
Other	54		39		126		78
Total operating revenues	1,253		1,220		3,096		2,809
Operating Expenses
Natural gas and petroleum products purchased	209		167		737		632
Operating, maintenance and other	405		410		768		742
Depreciation and amortization	199		196		399		382
Property and other taxes	102		93		215		193
Total operating expenses	915		866		2,119		1,949
Operating Income	338		354		977		860
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	85		72		246		182
Other income and expenses, net	6		22		15		55
Total other income and expenses	91		94		261		237
Interest Expense	176		160		354		309
Earnings Before Income Taxes	253		288		884		788
Income Tax Expense	65		62		229		192
Net Income	188		226		655		596
Net Income—Noncontrolling Interests	42		27		90		57
Net Income—Controlling Interests	$	146	$	199	$	565	$	539
Common Stock Data
Weighted-average shares outstanding
Basic	671		669		671		669
Diluted	673		671		672		671
Earnings per share
Basic	$	0.22	$	0.30	$	0.84	$	0.81
Diluted	$	0.22	$	0.30	$	0.84	$	0.80
Dividends per share	$	0.335	$	0.305	$	0.67	$	0.61

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In millions)



	Three Months Ended June 30,					Six Months Ended June 30,
	2014		2013			2014			2013
Net Income	$	188	$	226		$	655		$	596
Other comprehensive income (loss)
Foreign currency translation adjustments	223		(251		)	(25		)	(440		)
Unrealized mark-to-market net gain on hedges	1		—			3			3
Reclassification of cash flow hedges into earnings	1		2			3			4
Pension and benefits impact (net of taxes of $3, $5, $6 and $9, respectively)	6		10			13			21
Other	—		(1		)	—			—
Total other comprehensive income (loss)	231		(240		)	(6		)	(412		)
Total Comprehensive Income (Loss), net of tax	419		(14		)	649			184
Less: Comprehensive Income—Noncontrolling Interests	45		25			89			52
Comprehensive Income (Loss)—Controlling Interests	$	374	$	(39	)	$	560		$	132

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)



	June 30, 2014		December 31, 2013
ASSETS

Current Assets
Cash and cash equivalents	$	300	$	201
Receivables, net	1,222		1,336
Inventory	277		263
Fuel tracker	165		28
Other	241		253
Total current assets	2,205		2,081

Investments and Other Assets
Investments in and loans to unconsolidated affiliates	2,803		3,043
Goodwill	4,841		4,810
Other	398		385
Total investments and other assets	8,042		8,238

Property, Plant and Equipment
Cost	29,223		28,456
Less accumulated depreciation and amortization	6,963		6,627
Net property, plant and equipment	22,260		21,829

Regulatory Assets and Deferred Debits	1,439		1,385

Total Assets	$	33,946	$	33,533

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions, except per-share amounts)



	June 30, 2014		December 31, 2013
LIABILITIES AND EQUITY

Current Liabilities
Accounts payable	$	518	$	440
Commercial paper	769		1,032
Taxes accrued	103		72
Interest accrued	193		201
Current maturities of long-term debt	496		1,197
Other	1,077		1,097
Total current liabilities	3,156		4,039

Long-term Debt	13,141		12,488

Deferred Credits and Other Liabilities
Deferred income taxes	5,223		4,968
Regulatory and other	1,423		1,457
Total deferred credits and other liabilities	6,646		6,425

Commitments and Contingencies

Preferred Stock of Subsidiaries	258		258

Equity
Preferred stock, $0.001 par, 22 million shares authorized, no shares outstanding	—		—
Common stock, $0.001 par, 1 billion shares authorized, 671 million and 670 million shares outstanding at June 30, 2014 and December 31, 2013, respectively	1		1
Additional paid-in capital	4,918		4,869
Retained earnings	2,497		2,383
Accumulated other comprehensive income	1,236		1,241
Total controlling interests	8,652		8,494
Noncontrolling interests	2,093		1,829
Total equity	10,745		10,323

Total Liabilities and Equity	$	33,946	$	33,533

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In millions)



	Six Months Ended June 30,
	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	655		$	596
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	405			388
Deferred income tax expense	224			182
Equity in earnings of unconsolidated affiliates	(246		)	(182		)
Distributions received from unconsolidated affiliates	199			147
Other	(28		)	69
Net cash provided by operating activities	1,209			1,200
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(833		)	(959		)
Investments in and loans to unconsolidated affiliates	(30		)	(168		)
Acquisitions, net of cash acquired	—			(1,254		)
Purchases of held-to-maturity securities	(437		)	(456		)
Proceeds from sales and maturities of held-to-maturity securities	453			463
Purchases of available-for-sale securities	(13		)	(2,899		)
Proceeds from sales and maturities of available-for-sale securities	7			2,722
Distributions received from unconsolidated affiliates	242			13
Other changes in restricted funds	(1		)	1
Other	—			2
Net cash used in investing activities	(612		)	(2,535		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	712			1,848
Payments for the redemption of long-term debt	(736		)	(546		)
Net increase (decrease) in commercial paper	(256		)	440
Distributions to noncontrolling interests	(81		)	(69		)
Contributions from noncontrolling interests	112			—
Dividends paid on common stock	(453		)	(412		)
Proceeds from the issuance of Spectra Energy Partners, LP common units	191			190
Other	12			10
Net cash provided by (used in) financing activities	(499		)	1,461
Effect of exchange rate changes on cash	1			(3		)
Net increase in cash and cash equivalents	99			123
Cash and cash equivalents at beginning of period	201			94
Cash and cash equivalents at end of period	$	300		$	217
Supplemental Disclosures
Property, plant and equipment non-cash accruals	$	118		$	148

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

(In millions)



	Common Stock		Additional Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income
	Common Stock		Additional Paid-in Capital			Retained Earnings			Foreign Currency Translation Adjustments			Other			Noncontrolling Interests			Total
December 31, 2013	$	1	$	4,869		$	2,383		$	1,557		$	(316	)	$	1,829		$	10,323
Net income	—		—			565			—			—			90			655
Other comprehensive income (loss)	—		—			—			(24		)	19			(1		)	(6		)
Dividends on common stock	—		—			(451		)	—			—			—			(451		)
Stock-based compensation	—		6			—			—			—			—			6
Distributions to noncontrolling interests	—		—			—			—			—			(81		)	(81		)
Contributions from noncontrolling interests	—		—			—			—			—			112			112
Spectra Energy common stock issued	—		9			—			—			—			—			9
Spectra Energy Partners, LP common units issued	—		29			—			—			—			144			173
Transfer of interests in subsidiaries to Spectra Energy Partners, LP	—		—			—			—			—			1			1
Other, net	—		5						—			—			(1		)	4
June 30, 2014	$	1	$	4,918		$	2,497		$	1,533		$	(297	)	$	2,093		$	10,745

December 31, 2012	$	1	$	5,297		$	2,165		$	2,044		$	(535	)	$	871		$	9,843
Net income	—		—			539			—			—			57			596
Other comprehensive income (loss)	—		—			—			(435		)	28			(5		)	(412		)
Dividends on common stock	—		—			(410		)	—			—			—			(410		)
Stock-based compensation	—		4			—			—			—			—			4
Distributions to noncontrolling interests	—		—			—			—			—			(69		)	(69		)
Spectra Energy common stock issued	—		10			—			—			—			—			10
Spectra Energy Partners, LP common units issued	—		38			—			—			—			128			166
Other, net			(2		)	—									3			1
June 30, 2013	$	1	$	5,347		$	2,294		$	1,609		$	(507	)	$	985		$	9,729

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY CORP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. General

The terms “we,” “our,” “us” and “Spectra Energy” as used in this report refer collectively to Spectra Energy Corp and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity within Spectra Energy. The term “Spectra Energy Partners” refers to our Spectra Energy Partners operating segment. The term “SEP” refers to Spectra Energy Partners, LP, our master limited partnership.

Nature of Operations. Spectra Energy Corp, through its subsidiaries and equity affiliates, owns and operates a large and diversified portfolio of complementary natural gas-related energy assets, and owns and operates a crude oil pipeline system that connects Canadian and U.S. producers to refineries in the U.S. Rocky Mountain and Midwest regions. We currently operate in three key areas of the natural gas industry: gathering and processing, transmission and storage, and distribution. We provide transmission and storage of natural gas to customers in various regions of the northeastern and southeastern United States, the Maritime Provinces in Canada, the Pacific Northwest in the United States and Canada, and in the province of Ontario, Canada. We also provide natural gas sales and distribution services to retail customers in Ontario, and natural gas gathering and processing services to customers in western Canada. We also own a 50% interest in DCP Midstream, LLC (DCP Midstream), based in Denver, Colorado, one of the leading natural gas gatherers in the United States based on wellhead volumes, and one of the largest U.S. producers and marketers of natural gas liquids (NGLs).

Basis of Presentation. The accompanying Condensed Consolidated Financial Statements include our accounts and the accounts of our majority-owned subsidiaries, after eliminating intercompany transactions and balances. These interim financial statements should be read in conjunction with the consolidated financial statements included in our Annual Report on Form

10-K for the year ended December 31, 2013, and reflect all normal recurring adjustments that are, in our opinion, necessary to fairly present our results of operations and financial position. Amounts reported in the Condensed Consolidated Statements of Operations are not necessarily indicative of amounts expected for the respective annual periods due to the effects of seasonal temperature variations on energy consumption, primarily in our gas distribution operations, as well as changing commodity prices on certain of our processing operations and other factors.

Use of Estimates. To conform with generally accepted accounting principles (GAAP) in the United States, we make estimates and assumptions that affect the amounts reported in the Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.

2. Acquisition of Express-Platte

In March 2013, we acquired 100% of the ownership interests in the Express-Platte crude oil pipeline system for $1.5 billion, consisting of $1.25 billion in cash and $260 million of acquired debt, before working capital adjustments. The Express-Platte pipeline system, which begins in Hardisty, Alberta, and terminates in Wood River, Illinois, is comprised of both the Express and Platte crude oil pipelines. The Express pipeline carries crude oil to U.S. refining markets in the Rockies area, including Montana, Wyoming, Colorado and Utah. The Platte pipeline, which interconnects with Express pipeline in Casper, Wyoming, transports crude oil predominantly from the Bakken shale and western Canada to refineries in the Midwest. In 2013, subsidiaries of Spectra Energy contributed a 100% interest in the U.S. portion of Express-Platte and sold a 100% ownership interest in the Canadian portion to SEP.

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The following table summarizes the fair values of the assets and liabilities acquired as of the date of the acquisition.



	Purchase Price Allocation
	(in millions)
Cash purchase price	$	1,250
Working capital and other purchase adjustments	71
Total	1,321
Cash	67
Receivables	25
Other current assets	9
Property, plant and equipment	1,251
Accounts payable	(18		)
Other current liabilities	(17		)
Deferred credits and other liabilities	(259		)
Long-term debt, including current portion	(260		)
Total assets acquired/liabilities assumed	798
Goodwill	$	523

The purchase price is greater than the sum of fair values of the net assets acquired, resulting in goodwill as noted above. The goodwill reflects the value of the strategic location of the pipeline and the opportunity to grow the business. Goodwill related to the acquisition of Express-Platte is not deductible for income tax purposes.

The allocation of the fair values of assets and liabilities acquired related to the acquisition of Express-Platte was finalized in the first quarter of 2014, resulting in the following adjustments to amounts reported as of December 31, 2013: a $60 million decrease in Property, Plant and Equipment, a $1 million decrease in Other Current Assets and a $24 million decrease in Deferred Credits and Other Liabilities, resulting in a $37 million increase in Goodwill.

Pro forma results of operations that reflect the acquisition of Express-Platte as if the acquisition had occurred as of the beginning of 2013 are not presented as they do not materially differ from actual results reported in our Condensed Consolidated Statements of Operations.

3. Business Segments

In November 2013, Spectra Energy contributed substantially all of its remaining U.S. transmission, storage and liquids assets to SEP (the U.S. Assets Dropdown). As a result of this transaction, we realigned our reportable segments structure. Amounts presented herein for 2013 segment information have been recast to conform to our current segment reporting presentation. There were no changes to consolidated data as a result of the recast of our segment information.

We manage our business in four reportable segments: Spectra Energy Partners, Distribution, Western Canada Transmission & Processing and Field Services. The remainder of our business operations is presented as “Other,” and consists of unallocated corporate costs and employee benefit plan assets and liabilities, 100%-owned captive insurance subsidiaries and other miscellaneous activities.

Our chief operating decision maker (CODM) regularly reviews financial information about each of these segments in deciding how to allocate resources and evaluate performance. There is no aggregation within our reportable business segments.

The presentation of our Spectra Energy Partners segment is reflective of the parent-level focus by our CODM, considering the resource allocation and governance provisions associated with SEP’s master limited partnership structure. SEP maintains a capital and cash management structure that is separate from Spectra Energy’s, is self-funding and maintains its own lines of bank credit and cash management accounts. It is in this context that our CODM evaluates the Spectra Energy Partners segment as a whole, without regard to any of SEP’s individual businesses. These factors, coupled with a different cost of capital of our other businesses, serve to differentiate how our Spectra Energy Partners segment is managed as compared to how SEP is managed.

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Spectra Energy Partners provides transmission, storage and gathering of natural gas, as well as the transportation of crude oil and natural gas liquids (NGLs) through interstate pipeline systems for customers in various regions of the midwestern, northeastern and southeastern United States and Canada. The natural gas transmission and storage operations are primarily subject to the rules and regulations of the Federal Energy Regulatory Commission (FERC). The crude oil transportation operations are primarily subject to regulation by the FERC in the U.S. and the National Energy Board (NEB) in Canada. Our Spectra Energy Partners segment is composed of the operations of SEP, less governance costs, which are included in “Other.”

Distribution provides retail natural gas distribution service in Ontario, Canada, as well as natural gas transmission and storage services to other utilities and energy market participants. These services are provided by Union Gas Limited (Union Gas), and are primarily subject to the rules and regulations of the Ontario Energy Board (OEB).

Western Canada Transmission & Processing provides transmission of natural gas, natural gas gathering and processing services, and NGL extraction, fractionation, transportation, storage and marketing to customers in western Canada, the northern tier of the United States and the Maritime Provinces in Canada. This segment conducts business mostly through BC Pipeline, BC Field Services, and the NGL marketing and Canadian Midstream businesses, and Maritimes & Northeast Pipeline Limited Partnership (M&N Canada). BC Pipeline and BC Field Services operations are primarily subject to the rules and regulations of the NEB.

Field Services gathers, compresses, treats, processes, transports, stores and sells natural gas, produces, fractionates, transports, stores and sells NGLs, and recovers and sells condensate. In addition, Field Services trades and markets natural gas and NGLs. It conducts operations through DCP Midstream, which is owned 50% by us and 50% by Phillips 66. DCP Midstream gathers raw natural gas through gathering systems located in nine major conventional and non-conventional natural gas producing regions: Mid-Continent, Rocky Mountain, East Texas-North Louisiana, Barnett Shale, Gulf Coast, South Texas, Central Texas, Antrim Shale and Permian Basin. DCP Midstream Partners, LP (DCP Partners) is a publicly-traded master limited partnership, of which DCP Midstream acts as general partner. As of June 30, 2014, DCP Midstream had an approximate 22% ownership interest in DCP Partners, including DCP Midstream’s limited partner and general partner interests.

Our reportable segments offer different products and services and are managed separately as business units. Management evaluates segment performance based on earnings from continuing operations before interest, taxes, and depreciation and amortization (EBITDA). Cash, cash equivalents and short-term investments are managed at the parent-company levels, so the associated gains and losses from foreign currency transactions, and interest and dividend income are excluded from the segments’ EBITDA. Our segment EBITDA may not be comparable to similarly titled measures of other companies because other companies may not calculate EBITDA in the same manner. Transactions between reportable segments are accounted for on the same basis as transactions with unaffiliated third parties.

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Business Segment Data



Condensed Consolidated Statements of Operations
	Unaffiliated Revenues		Intersegment Revenues			Total Operating Revenues			Depreciation and Amortization		Segment EBITDA/ Consolidated Earnings before Income Taxes
	(in millions)
Three Months Ended June 30, 2014
Spectra Energy Partners	$	531	$	—		$	531		$	72	$	374
Distribution	360		—			360			48		112
Western Canada Transmission & Processing	360		31			391			68		111
Field Services	—		—			—			—		54
Total reportable segments	1,251		31			1,282			188		651
Other	2		17			19			11		(24		)
Eliminations	—		(48		)	(48		)	—		—
Depreciation and amortization	—		—			—			—		199
Interest expense	—		—			—			—		176
Interest income and other	—		—			—			—		1
Total consolidated	$	1,253	$	—		$	1,253		$	199	$	253

Three Months Ended June 30, 2013
Spectra Energy Partners	$	492	$	—		$	492		$	65	$	358
Distribution	352		—			352			51		115
Western Canada Transmission & Processing	373		18			391			70		157
Field Services	—		—			—			—		46
Total reportable segments	1,217		18			1,235			186		676
Other	3		15			18			10		(29		)
Eliminations	—		(33		)	(33		)	—		—
Depreciation and amortization	—		—			—			—		196
Interest expense	—		—			—			—		160
Interest income and other	—		—			—			—		(3		)
Total consolidated	$	1,220	$	—		$	1,220		$	196	$	288

Six Months Ended June 30, 2014
Spectra Energy Partners	$	1,112	$	—		$	1,112		$	145	$	803
Distribution	1,078		—			1,078			97		338
Western Canada Transmission & Processing	901		65			966			135		348
Field Services	—		—			—			—		184
Total reportable segments	3,091		65			3,156			377		1,673
Other	5		32			37			22		(41		)
Eliminations	—		(97		)	(97		)	—		—
Depreciation and amortization	—		—			—			—		399
Interest expense	—		—			—			—		354
Interest income and other	—		—			—			—		5
Total consolidated	$	3,096	$	—		$	3,096		$	399	$	884

Six Months Ended June 30, 2013
Spectra Energy Partners	$	951	$	—		$	951		$	126	$	705
Distribution	1,051		—			1,051			102		335
Western Canada Transmission & Processing	801		33			834			134		347
Field Services	—		—			—			—		134
Total reportable segments	2,803		33			2,836			362		1,521
Other	6		30			36			20		(43		)
Eliminations	—		(63		)	(63		)	—		—
Depreciation and amortization	—		—			—			—		382
Interest expense	—		—			—			—		309
Interest income and other	—		—			—			—		1
Total consolidated	$	2,809	$	—		$	2,809		$	382	$	788

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4. Regulatory Matters

Union Gas. In January 2014, Union Gas filed a notice of motion seeking leave to appeal to the Ontario Court of Appeal (Court of Appeal) for the unsuccessful appeal to the Ontario Divisional Court on the OEB’s treatment of 2011 revenues derived from the optimization of our upstream transportation contracts. A decision from the Court of Appeal on the notice of motion was issued in April 2014 granting leave to appeal. In May 2014, Union Gas filed a notice of appeal and a hearing is scheduled for December 2014.

Union Gas filed an application with the OEB in May 2013 for the annual disposition of the 2012 non-commodity deferral account balances. A decision on that application was issued by the OEB in March 2014. Among other things, the OEB determined that revenues derived from the optimization of Union Gas’ upstream transportation contracts in 2012 will be treated as revenues and included in utility earnings instead of a reduction to gas costs. The decision also denied a proposal to recover certain over-refunds to customers and reduced incentive amounts related to Union Gas’ 2011 energy conservation program. As a result of this OEB decision, Union Gas recognized pre-tax income of $10 million in the first quarter of 2014, comprised of a $32 million increase in Transportation, Storage and Processing of Natural Gas revenues, a $15 million decrease in Distribution of Natural Gas revenues and a $7 million decrease in Other revenues on the Condensed Consolidated Statements of Operations. In addition, the decision also approved the deferral of pension expense for recovery from customers, resulting in pre-tax income of $7 million, recorded as a reduction in Operating, Maintenance and Other expense in the second quarter of 2014.

On May 2, 2014, Union Gas filed an application with the OEB for the annual disposition of its 2013 non-commodity deferral account balances. The combined impact is a net payable to customers of approximately $21 million which is primarily reflected as Current Liabilities—Other on the Condensed Consolidated Balance Sheets at June 30, 2014. A hearing and decision from the OEB is expected later this year.

5. Income Taxes

Income tax expense was $65 million for the three months ended June 30, 2014, compared with $62 million for the same period in 2013. The higher tax expense was driven by the reversal of tax reserves in the 2013 period as a result of favorable Canadian federal income tax legislation enacted in the second quarter of 2013, mostly offset by lower Canadian earnings in 2014.

Income tax expense was $229 million for the six months ended June 30, 2014, compared with $192 million for the same period in 2013. The higher tax expense was driven primarily by higher earnings and the reversal of tax reserves in the 2013 period.

The effective income tax rate for the three months ended June 30, 2014 and 2013 was 26% and 22%, respectively, and 26% and 24% for the six-month periods, respectively. The lower effective tax rates in the 2013 periods resulted primarily from the reversal of tax reserves in the second quarter of 2013.

There was no material net change in unrecognized tax benefits recorded during the six-month period ended June 30, 2014. Although uncertain, we believe it is reasonably possible that the total amount of unrecognized tax benefits could decrease by approximately $15 million to $20 million prior to June 30, 2015.

In September 2013, the U.S. Treasury and the Internal Revenue Service (IRS) issued final regulations regarding the deduction and capitalization of expenditures related to tangible property (tangible property regulations). The final IRS regulations apply to amounts paid to acquire, produce, or improve tangible property as well as dispositions of such property and are for tax years beginning on or after January 1, 2014. We are currently evaluating the tangible property regulations and awaiting the release of additional regulations and industry specific guidance. Any changes resulting from the tangible property regulations will affect the timing of deducting expenditures for tax purposes and the impact will be reflected in income tax payable or receivable, deferred taxes and cash paid for income taxes. Our earnings will not be impacted.

6. Earnings per Common Share

Basic earnings per common share (EPS) is computed by dividing net income from controlling interests by the weighted-average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income from controlling interests by the diluted weighted-average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options, stock-based performance unit awards and phantom stock awards, were exercised, settled or converted into common stock.

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The following table presents our basic and diluted EPS calculations:



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
	(in millions, except per-share amounts)

Net income—controlling interests	$	146	$	199	$	565	$	539
Weighted-average common shares outstanding
Basic	671		669		671		669
Diluted	673		671		672		671
Basic earnings per common share (a)	$	0.22	$	0.30	$	0.84	$	0.81
Diluted earnings per common share (a)	$	0.22	$	0.30	$	0.84	$	0.80

—————

(a) Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to

rounding.

7. Accumulated Other Comprehensive Income

The following table presents the net of tax changes in Accumulated Other Comprehensive Income (AOCI) by component and amounts reclassified out of AOCI to Net Income, excluding amounts attributable to noncontrolling interests:



	Foreign Currency Translation Adjustments			Pension and Post-retirement Benefit Plan Obligations				Gas Purchase Contract Hedges			Other			Total Accumulated Other Comprehensive Income
							(in millions)
March 31, 2014	$	1,313		$	(297	)		$	(7	)	$	(1	)	$	1,008
Reclassified to net income	—			—				—			1			1
Other AOCI activity	220			6				1			—			227
June 30, 2014	$	1,533		$	(291	)		$	(6	)	$	—		$	1,236

March 31, 2013	$	1,858		$	(496	)		$	(18	)	$	(4	)	$	1,340
Reclassified to net income	—			—				1			1			2
Other AOCI activity	(249		)	10				—			(1		)	(240		)
June 30, 2013	$	1,609		$	(486	)		$	(17	)	$	(4	)	$	1,102

December 31, 2013	$	1,557		$	(304	)		$	(11	)	$	(1	)	$	1,241
Reclassified to net income	—			—				2			1			3
Other AOCI activity	(24		)	13				3			—			(8		)
June 30, 2014	$	1,533		$	(291	)		$	(6	)	$	—		$	1,236

December 31, 2012	$	2,044		$	(507	)		$	(23	)	$	(5	)	$	1,509
Reclassified to net income	—			—				3			1			4
Other AOCI activity	(435		)	21				3			—			(411		)
June 30, 2013	$	1,609		$	(486	)		$	(17	)	$	(4	)	$	1,102

Reclassifications to Net Income are primarily included in Other Income and Expenses, Net on our Condensed Consolidated Statements of Operations.

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8. Inventory

Inventory consists of natural gas and NGLs held in storage for transmission and processing, and also includes materials and supplies. Natural gas inventories primarily relate to the Distribution segment in Canada and are valued at costs approved by the OEB. The difference between the approved price and the actual cost of gas purchased is recorded as either a receivable or a current liability, as appropriate, for future disposition with customers, subject to approval by the OEB. The remaining inventory is recorded at the lower of cost or market, primarily using average cost. The components of inventory are as follows:



	June 30, 2014		December 31, 2013
	(in millions)
Natural gas	$	166	$	155
NGLs	33		30
Materials and supplies	78		78
Total inventory	$	277	$	263

9. Investments in and Loans to Unconsolidated Affiliates

Our most significant investment in unconsolidated affiliates is our 50% investment in DCP Midstream, which is accounted for under the equity method of accounting. The following represents summary financial information for DCP Midstream, presented at 100%:



	Three Months Ended June 30,				Six Months Ended June 30,
	2014		2013		2014		2013
	(in millions)
Operating revenues	$	3,541	$	2,861	$	7,456	$	5,473
Operating expenses	3,387		2,671		7,032		5,121
Operating income	154		190		424		352
Net income	92		142		295		262
Net income attributable to members’ interests	89		78		254		169

DCP Partners issues, from time to time, limited partner units to the public, which are recorded by DCP Midstream directly to its equity. Our proportionate share of gains from those issuances, totaling $9 million and $7 million in the second quarters of 2014 and 2013, respectively, and $57 million and $50 million during the six-month periods ended June 30, 2014 and 2013, respectively, are reflected in Equity in Earnings of Unconsolidated Affiliates in the Condensed Consolidated Statements of Operations.

10. Goodwill

We perform our goodwill impairment test annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. We completed our annual goodwill impairment test as of April 1, 2014 and no impairments were identified.

We perform our annual review for goodwill impairment at the reporting unit level, which is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. We determined that our reporting units are equivalent to our reportable segments, except for the reporting units of our Western Canada Transmission & Processing reportable segment and our Spectra Energy Partners reportable segment, which are one level below.

As permitted under accounting guidance on testing goodwill for impairment, we perform either a qualitative assessment or a quantitative assessment of each of our reporting units based on management’s judgment. With respect to our qualitative assessments, we consider events and circumstances specific to us, such as macroeconomic conditions, industry and market considerations, cost factors and overall financial performance, when evaluating whether it is more likely than not that the fair values of our reporting units are less than their respective carrying amounts.

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The following presents changes in goodwill during 2014:



	Goodwill
	(in millions)
December 31, 2013	$	4,810
Acquisition of Express-Platte	37
Foreign currency translation	(6		)
June 30, 2014	$	4,841

See Note 2 for discussion of the acquisition of Express-Platte and an adjustment to Goodwill recorded in the first quarter of 2014 related to the acquisition.

11. Marketable Securities and Restricted Funds

We routinely invest excess cash and various restricted balances in securities such as commercial paper, bankers acceptances, corporate debt securities, treasury bills and money market funds in the United States and Canada. We do not purchase marketable securities for speculative purposes, therefore we do not have any securities classified as trading securities. While we do not routinely sell marketable securities prior to their scheduled maturity dates, some of our investments may be held and restricted for insurance purposes, so these investments are classified as available-for-sale (AFS) marketable securities as they may occasionally be sold prior to their scheduled maturity dates due to the unexpected timing of cash needs. Initial investments in securities are classified as purchases of the respective type of securities (AFS marketable securities or held-to-maturity (HTM) marketable securities). Maturities of securities are classified within proceeds from sales and maturities of securities in the Condensed Consolidated Statements of Cash Flows.

AFS Securities. AFS securities are as follows:



	Estimated Fair Value
	June 30, 2014		December 31, 2013
	(in millions)
Corporate debt securities	$	24	$	18
Money market funds	1		1
Total available-for-sale securities	$	25	$	19

Our AFS securities are classified on the Condensed Consolidated Balance Sheets as follows:



	Estimated Fair Value
	June 30, 2014		December 31, 2013
	(in millions)
Restricted funds
Investments and other assets—other	$	1	$	1
Non-restricted funds
Current assets—other	—		7
Investments and other assets—other	24		11
Total available-for-sale securities	$	25	$	19

At June 30, 2014, the weighted-average contractual maturity of outstanding AFS securities was two years.

There were no material gross unrealized holding gains or losses associated with investments in AFS securities at June 30, 2014 or December 31, 2013.

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HTM Securities. All of our HTM securities are restricted funds and are as follows:



		Estimated Fair Value
Description	Condensed Consolidated Balance Sheet Caption	June 30, 2014		December 31, 2013
		(in millions)
Bankers acceptances	Current assets—other	$	35	$	35
Canadian government securities	Current assets—other	33		34
Money market funds	Current assets—other	4		3
Canadian government securities	Investments and other assets—other	125		131
Bankers acceptances	Investments and other assets—other	—		10
Total held-to-maturity securities		$	197	$	213

All of our HTM securities are restricted funds pursuant to certain M&N Canada and Express-Platte debt agreements. The funds restricted for M&N Canada, plus future cash from operations that would otherwise be available for distribution to the partners of M&N Canada, are required to be placed in escrow until the balance in escrow is sufficient to fund all future debt service on the M&N Canada 6.90% senior secured notes. There are sufficient funds held in escrow to fund all future debt service on these M&N Canada notes.

At June 30, 2014, the weighted-average contractual maturity of outstanding HTM securities was one year.

There were no material gross unrecognized holding gains or losses associated with investments in HTM securities at June 30, 2014 or December 31, 2013.

Other Restricted Funds. In addition to the portions of the AFS and HTM securities that were restricted funds as described above, we had other restricted funds totaling $20 million at June 30, 2014 and $19 million at December 31, 2013 classified as Current Assets—Other. These restricted funds are related to additional amounts for the M&N Canada debt service requirements and insurance.

Changes in restricted funds’ balances are presented within Cash Flows from Investing Activities on our Condensed Consolidated Statements of Cash Flows.

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12. Debt and Credit Facilities

Available Credit Facilities and Restrictive Debt Covenants



	Expiration Date	Total Credit Facilities Capacity		Commercial Paper Outstanding at June 30, 2014		Available Credit Facilities Capacity
	Expiration Date	Total Credit Facilities Capacity		Commercial Paper Outstanding at June 30, 2014		Available Credit Facilities Capacity
		(in millions)
Spectra Energy Capital, LLC (a)	2018	$	1,000	$	220	$	780
SEP (b)	2018	2,000		549		1,451
Westcoast Energy Inc. (c)	2016	281		—		281
Union Gas (d)	2016	375		—		375
Total		$	3,656	$	769	$	2,887

___________


(a)	Revolving credit facility contains a covenant requiring the Spectra Energy Corp consolidated debt-to-total capitalization ratio, as defined in the agreement, to not exceed 65%. Per the terms of the agreement, collateralized debt is excluded from the calculation of the ratio. This ratio was 56% at June 30, 2014.

(b)

Revolving credit facility contains a covenant that requires SEP to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the credit agreement, of 5.0 to 1 or less, provided that for three fiscal quarters subsequent to certain acquisitions (such as the November 1, 2013 U.S. Assets Dropdown from Spectra Energy Corp), the ratio may be 5.5 to 1 or less. As of June 30, 2014, this ratio was 3.9 to 1 after giving effect to the U.S. Assets Dropdown.


(c)	U.S. dollar equivalent at June 30, 2014. The revolving credit facility is 300 million Canadian dollars and contains a covenant that requires the Westcoast Energy Inc. non-consolidated debt-to-total capitalization ratio to not exceed 75%. The ratio was 41% at June 30, 2014.


(d)	U.S. dollar equivalent at June 30, 2014. The revolving credit facility is 400 million Canadian dollars and contains a covenant that requires the Union Gas debt-to-total capitalization ratio to not exceed 75% and a provision which requires Union Gas to repay all borrowings under the facility for a period of two days during the second quarter of each year. The ratio was 65% at June 30, 2014.

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facilities. As of June 30, 2014, there were no letters of credit issued or revolving borrowings outstanding under the credit facilities.

Our credit agreements contain various covenants, including the maintenance of certain financial ratios. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of June 30, 2014, we were in compliance with those covenants. In addition, our credit agreements allow for acceleration of payments or termination of the agreements due to nonpayment, or in some cases, due to the acceleration of other significant indebtedness of the borrower or some of its subsidiaries. Our debt and credit agreements do not contain provisions that trigger an acceleration of indebtedness based solely on the occurrence of a material adverse change in our financial condition or results of operations.

Debt Issuances. On June 2, 2014, Union Gas issued 200 million Canadian dollars (approximately $183 million as of the issuance date) of 2.76% unsecured notes due 2021 and 250 million Canadian dollars (approximately $229 million as of the issuance date) of 4.20% unsecured notes due 2044. Net proceeds from the offerings were used for general corporate purposes.

In January 2014, Spectra Energy Capital, LLC (Spectra Capital) borrowed the full $300 million available under its unsecured term loan agreement. Interest on the borrowing is based on LIBOR (London Interbank Offered Rate) and the borrowing is due in 2018. Net proceeds from the borrowing were used for general corporate purposes.

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13. Fair Value Measurements

The following presents, for each of the fair value hierarchy levels, assets and liabilities that are measured and recorded at fair value on a recurring basis:



Description	Condensed Consolidated Balance Sheet Caption	June 30, 2014
Description	Condensed Consolidated Balance Sheet Caption	Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	73	$	—	$	73	$	—
Banker acceptances	Cash and cash equivalents	3		—		3		—
Interest rate swaps	Current assets—other	4		—		4		—
Corporate debt securities	Investments and other assets—other	24		—		24		—
Interest rate swaps	Investments and other assets—other	19		—		19		—
Money market funds	Investments and other assets—other	1		1		—		—
Total Assets		$	124	$	1	$	123	$	—
Commodity derivatives	Current liabilities—other	$	6	$	—	$	—	$	6
Interest rate swaps	Current liabilities—other	3		—		3		—
Natural gas purchase contracts	Deferred credits and other liabilities—regulatory and other	1		—		—		1
Commodity derivatives	Deferred credits and other liabilities—regulatory and other	2		—		—		2
Total Liabilities		$	12	$	—	$	3	$	9



Description	Condensed Consolidated Balance Sheet Caption	December 31, 2013
Description	Condensed Consolidated Balance Sheet Caption	Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	49	$	—	$	49	$	—
Corporate debt securities	Current assets—other	7		—		7		—
Interest rate swaps	Current assets—other	8		—		8		—
Corporate debt securities	Investments and other assets—other	11		—		11		—
Interest rate swaps	Investments and other assets—other	15		—		15		—
Money market funds	Investments and other assets—other	1		1		—		—
Total Assets		$	91	$	1	$	90	$	—
Natural gas purchase contracts	Deferred credits and other liabilities—regulatory and other	$	3	$	—	$	—	$	3
Interest rate swaps	Deferred credits and other liabilities—regulatory and other	6		—		6		—
Total Liabilities		$	9	$	—	$	6	$	3

The following presents changes in Level 3 liabilities that are measured at fair value on a recurring basis using significant unobservable inputs:



	Three Months Ended June 30,					Six Months Ended June 30,
	2014			2013		2014			2013
	(in millions)
Derivative liabilities
Fair value, beginning of period	$	5		$	6	$	3		$	9
Total realized/unrealized losses (gains):
Included in earnings	5			—		9			1
Included in other comprehensive income	(1		)	—		(4		)	(4		)
Settlements	—			—		1			—
Fair value, end of period	$	9		$	6	$	9		$	6
Total losses for the period included in earnings (or changes in net assets) attributable to the change in unrealized gains or losses relating to liabilities held at the end of the period	$	4		$	—	$	7		$	1

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Level 1

Level 1 valuations represent quoted unadjusted prices for identical instruments in active markets.

Level 2 Valuation Techniques

Fair values of our financial instruments that are actively traded in the secondary market, including our long-term debt, are determined based on market-based prices. These valuations may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.

For interest rate swaps, we utilize data obtained from a third-party source for the determination of fair value. Both the future cash flows for the fixed-leg and floating-leg of our swaps are discounted to present value. In addition, credit default swap rates are used to develop the adjustment for credit risk embedded in our positions. We believe that since some of the inputs and assumptions for the calculations of fair value are derived from observable market data, a Level 2 classification is appropriate.

Level 3 Valuation Techniques

We do not have significant amounts of assets or liabilities measured and reported using Level 3 valuation techniques, which include the use of pricing models, discounted cash flow methodologies or similar techniques where at least one significant model assumption or input is unobservable. Level 3 financial instruments also include those for which the determination of fair value requires significant management judgment or estimation.

For natural gas purchases contracts and commodity derivatives, we utilize data obtained from third-party sources for the determination of fair value. The expected future cash flows arising from our swaps are discounted to present value. In addition, credit default swap rates or historical average credit default rates by credit rating are used to develop the adjustment for credit risk embedded in our positions. As these transactions are limited, we believe a Level 3 classification is appropriate.

Financial Instruments

The fair values of financial instruments that are recorded and carried at book value are summarized in the following table. Judgment is required in interpreting market data to develop the estimates of fair value. These estimates are not necessarily indicative of the amounts we could have realized in current markets.



	June 30, 2014				December 31, 2013
	Book Value		Approximate Fair Value		Book Value		Approximate Fair Value
	(in millions)
Note receivable, noncurrent (a)	$	71	$	71	$	71	$	71
Long-term debt, including current maturities (b)	13,625		15,226		13,668		14,701

__________


(a)	Included within Investments in and Loans to Unconsolidated Affiliates.


(b)	Excludes unamortized items and fair value hedge carrying value adjustments.

The fair value of our long-term debt is determined based on market-based prices as described in the Level 2 valuation technique described above and is classified as Level 2.

The fair values of cash and cash equivalents, restricted cash, short-term investments, accounts receivable, note receivable-noncurrent, accounts payable and commercial paper are not materially different from their carrying amounts because of the short-term nature of these instruments or because the stated rates approximate market rates.

During the 2014 and 2013 periods, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

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14. Risk Management and Hedging Activities

We are exposed to the impact of market fluctuations in the prices of NGLs and natural gas purchased as a result of our investment in DCP Midstream, the ownership of the NGL marketing operations in western Canada and processing associated with our U.S. pipeline assets. Exposure to interest rate risk exists as a result of the issuance of variable and fixed-rate debt and commercial paper. We are exposed to foreign currency risk from our Canadian operations. We employ established policies and procedures to manage our risks associated with these market fluctuations, which may include the use of derivatives, mostly around interest rate and commodity exposures.

DCP Midstream manages their direct exposure to market prices separate from Spectra Energy, and utilizes various risk management strategies, including the use of commodity derivatives.

Other than interest rate swaps and commodity derivatives described below, we did not have any significant derivatives outstanding during the six months ended June 30, 2014.

Interest Rate Swaps

At June 30, 2014, we had “pay floating—receive fixed” interest rate swaps outstanding with a total notional principal amount of $1,617 million to hedge against changes in the fair value of our fixed-rate debt that arise as a result of changes in market interest rates. These swaps also allow us to transform a portion of the underlying interest payments related to our long-term fixed-rate debt securities into variable-rate interest payments in order to achieve our desired mix of fixed and variable-rate debt.

Information about our interest rate swaps that had netting or rights of offset arrangements are as follows:



	June 30, 2014						December 31, 2013
	Gross Amounts Presented in the Condensed Consolidated Balance Sheets		Amounts Not Offset in the Condensed Consolidated Balance Sheets		Net Amount		Gross Amounts Presented in the Condensed Consolidated Balance Sheets		Amounts Not Offset in the Condensed Consolidated Balance Sheets		Net Amount
Description	(in millions)
Assets	$	23	$	2	$	21	$	23	$	3	$	20
Liabilities	3		2		1		6		3		3

At June 30, 2014, we had interest rate swaps with another counterparty which were in a liability position of $2 million which could be terminated by the counterparty if one of our credit ratings falls below investment grade. In addition, we had one interest rate swap with a counterparty which was in a liability position of $1 million which could be terminated at any time.

Commodity Derivatives

Effective January 2014, we instituted a commodity price risk management program at Western Canada Transmission & Processing’s Empress NGL business and elected to not apply cash flow hedge accounting.

At June 30, 2014, we had commodity mark-to-market derivatives outstanding with a total notional amount of 129 million gallons. The longest dated commodity derivative contract we currently have expires in 2017.

Information about our commodity derivatives that had netting or rights of offset arrangements are as follows:



	June 30, 2014
	Gross Amounts		Gross Amounts Offset		Net Amount Presented in the Condensed Consolidated Balance Sheets
Description	(in millions)
Assets	$	140	$	140	$	—
Liabilities	148		140		8

Substantially all of our commodity derivative agreements outstanding at June 30, 2014 have provisions that require collateral to be posted in the amount of the net liability position if one of our credit ratings falls below investment grade.

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Information regarding the impacts of commodity derivatives on our Condensed Consolidated Statements of Operations are as follows:



		Periods Ended June 30, 2014
Derivatives	Condensed Consolidated Statement of Operations Caption	Three Months			Six Months
		(in millions)
Commodity derivatives	Sales of natural gas liquids	$	(4	)	$	(7	)

15. Commitments and Contingencies

Environmental

We are subject to various U.S. federal, state and local laws and regulations, as well as Canadian federal and provincial laws, regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These laws and regulations can change from time to time, imposing new obligations on us.

Like others in the energy industry, we and our affiliates are responsible for environmental remediation at various contaminated sites. These include some properties that are part of our ongoing operations, sites formerly owned or used by us, and sites owned by third parties. Remediation typically involves management of contaminated soils and may involve groundwater remediation. Managed in conjunction with relevant federal, state/provincial and local agencies, activities vary with site conditions and locations, remedial requirements, complexity and sharing of responsibility. If remediation activities involve statutory joint and several liability provisions, strict liability, or cost recovery or contribution actions, we or our affiliates could potentially be held responsible for contamination caused by other parties. In some instances, we may share liability associated with contamination with other potentially responsible parties, and may also benefit from contractual indemnities that cover some or all cleanup costs. All of these sites generally are managed in the normal course of business or affiliated operations. We believe there are no matters outstanding that upon resolution will have a material effect on our consolidated results of operations, financial position or cash flows.