10-Q

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 March 31, 2017

or

¨ 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 1-33556

SPECTRA ENERGY PARTNERS, LP

(Exact Name of Registrant as Specified in its Charter)

Delaware	41-2232463
(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, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

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

Smaller reporting company  ¨ Emerging growth company  ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  ý

At March 31, 2017, there were 309,242,850 common units and 6,311,079 general partner units outstanding.

SPECTRA ENERGY PARTNERS, LP

FORM 10-Q FOR THE QUARTER ENDED

March 31, 2017

INDEX

		Page
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)	4
	Condensed Consolidated Statements of Operations for the three months ended March 31, 2017 and 2016	4
	Condensed Consolidated Statements of Comprehensive Income for the three months ended March 31, 2017 and 2016	5
	Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016	6
	Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2017 and 2016	8
	Condensed Consolidated Statements of Equity for the three months ended March 31, 2017 and 2016	9
	Notes to Condensed Consolidated Financial Statements	10
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	27
Item 4.	Controls and Procedures	27
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	28
Item 1A.	Risk Factors	28
Item 5.	Other Information.	28
Item 6.	Exhibits	28
	Signatures	30

2

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 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;

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

• the performance of natural gas transmission, storage and gathering facilities, and crude oil transportation and storage;

• the extent of success in connecting natural gas and oil supplies to transmission and gathering 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 Partners, LP has described. Spectra Energy Partners, LP 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 PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In millions, except per-unit amounts)

	Three Months Ended March 31,
	2017		2016
Operating Revenues
Transportation of natural gas	$	538	$	484
Transportation of crude oil	101		86
Storage of natural gas and other	61		54
Total operating revenues	700		624
Operating Expenses
Operating, maintenance and other	227		179
Depreciation and amortization	85		77
Property and other taxes	56		44
Total operating expenses	368		300
Operating Income	332		324
Other Income and Expenses
Earnings from equity investments	38		27
Other income and expenses, net	45		20
Total other income and expenses	83		47
Interest Expense	56		56
Earnings Before Income Taxes	359		315
Income Tax Expense	5		4
Net Income	354		311
Net Income—Noncontrolling Interests	37		13
Net Income—Controlling Interests	$	317	$	298
Calculation of Limited Partners’ Interest in Net Income:
Net income—Controlling Interests	$	317	$	298
Less: General partner’s interest in net income	89		69
Limited partners’ interest in net income	$	228	$	229
Weighted average limited partner units outstanding—basic and diluted	309		285
Net income per limited partner unit—basic and diluted	$	0.74	$	0.80
Distributions paid per limited partner unit	$	0.68875	$	0.63875

See Notes to Condensed Consolidated Financial Statements.

4

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In millions)

	Three Months Ended March 31,
	2017		2016
Net Income	$	354	$	311
Other comprehensive income:
Foreign currency translation adjustments	1		11
Total other comprehensive income	1		11
Total Comprehensive Income	355		322
Less: Comprehensive Income—Noncontrolling Interests	37		13
Comprehensive Income—Controlling Interests	$	318	$	309

See Notes to Condensed Consolidated Financial Statements.

5

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)

	March 31, 2017		December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	282	$	216
Receivables, net	339		380
Inventory	40		40
Fuel tracker	7		6
Other	17		18
Total current assets	685		660
Investments and Other Assets
Investments in and loans to unconsolidated affiliates	1,200		1,127
Goodwill	3,234		3,234
Other	98		108
Total investments and other assets	4,532		4,469
Property, Plant and Equipment
Cost	20,735		19,958
Less accumulated depreciation and amortization	3,940		3,866
Net property, plant and equipment	16,795		16,092
Regulatory Assets and Deferred Debits	409		385
Total Assets	$	22,421	$	21,606

See Notes to Condensed Consolidated Financial Statements.

6

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)

	March 31, 2017			December 31, 2016
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	486		$	441
Commercial paper	1,051			574
Taxes accrued	59			76
Interest accrued	43			79
Current maturities of long-term debt	415			416
Other	145			193
Total current liabilities	2,199			1,779
Long-term Debt	6,212			6,223
Deferred Credits and Other Liabilities
Deferred income taxes	43			42
Regulatory and other	154			158
Total deferred credits and other liabilities	197			200
Commitments and Contingencies
Equity
Partners’ Capital
Common units (309.2 million and 308.4 million units issued and outstanding at March 31, 2017 and December 31, 2016, respectively)	11,703			11,650
General partner units (6.3 million units issued and outstanding at March 31, 2017 and December 31, 2016)	481			452
Accumulated other comprehensive loss	(44		)	(45		)
Total partners’ capital	12,140			12,057
Noncontrolling interests	1,673			1,347
Total equity	13,813			13,404
Total Liabilities and Equity	$	22,421		$	21,606

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In millions)

	Three Months Ended March 31,
	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	354		$	311
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	85			79
Deferred income tax expense	1			1
Earnings from equity investments	(38		)	(27		)
Distributions from equity investments	27			26
Other	(65		)	(93		)
Net cash provided by operating activities	364			297
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(738		)	(468		)
Investments in and loans to unconsolidated affiliates	(70		)	(27		)
Purchase of intangible, net	—			(48		)
Distributions from equity investments	11			39
Purchases of held-to-maturity securities	(4		)	(11		)
Proceeds from sales and maturities of held-to-maturity securities	3			3
Purchases of available-for-sale securities	(68		)	(161		)
Proceeds from sales and maturities of available-for-sale securities	76			163
Other changes in restricted funds	2			4
Other	—			(2		)
Net cash used in investing activities	(788		)	(508		)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(10		)	—
Net increase in commercial paper	477			330
Distributions to noncontrolling interests	(12		)	(7		)
Contributions from noncontrolling interests	290			95
Proceeds from the issuances of units	39			82
Distributions to partners	(294		)	(243		)
Net cash provided by financing activities	490			257
Net increase in cash and cash equivalents	66			46
Cash and cash equivalents at beginning of period	216			168
Cash and cash equivalents at end of period	$	282		$	214
Supplemental Disclosures
Property, plant and equipment non-cash accruals	$	261		$	142

See Notes to Condensed Consolidated Financial Statements.

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SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

(In millions)

	Partners’ Capital									Noncontrolling Interests			Total
	Common			General Partner			Accumulated Other Comprehensive Income (Loss)
December 31, 2016	$	11,650		$	452		$	(45	)	$	1,347		$	13,404
Net income	228			89			—			37			354
Other comprehensive income	—			—			1			—			1
Attributed deferred tax benefit	—			20			—			11			31
Issuances of units	38			1			—			—			39
Distributions to partners	(213		)	(81		)	—			—			(294		)
Contributions from noncontrolling interests	—			—			—			290			290
Distributions to noncontrolling interests	—			—			—			(12		)	(12		)
March 31, 2017	$	11,703		$	481		$	(44	)	$	1,673		$	13,813
December 31, 2015	$	10,527		$	336		$	(50	)	$	533		$	11,346
Net income	229			69			—			13			311
Other comprehensive income	—			—			11			—			11
Attributed deferred tax benefit	—			10			—			2			12
Issuances of units	80			2			—			—			82
Distributions to partners	(182		)	(61		)	—			—			(243		)
Contributions from noncontrolling interests	—			—			—			95			95
Distributions to noncontrolling interests	—			—			—			(7		)	(7		)
March 31, 2016	$	10,654		$	356		$	(39	)	$	636		$	11,607

See Notes to Condensed Consolidated Financial Statements.

9

SPECTRA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. General

The terms “we,” “our,” “us” and “Spectra Energy Partners” as used in this report refer collectively to Spectra Energy Partners, LP 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 Partners.

Nature of Operations. Spectra Energy Partners, through its subsidiaries and equity affiliates, is engaged in the transmission, storage and gathering of natural gas and the transportation and storage of crude oil through interstate pipeline systems. We are a Delaware master limited partnership.

On February 27, 2017, Enbridge Inc. (Enbridge) and Spectra Energy Corp (Spectra Energy) completed a stock-for-stock merger transaction (the Merger) pursuant to which Spectra Energy merged with and into a direct, wholly owned subsidiary of Enbridge, with Spectra Energy continuing as the surviving corporation and a wholly owned subsidiary of Enbridge, and each outstanding share of common stock of Spectra Energy was automatically converted into, and became exchangeable for, 0.984 of Enbridge common share. As a result of the Merger, we became an indirect subsidiary of Enbridge through Enbridge’s ownership of Spectra Energy. As of March 31, 2017, Enbridge and its subsidiaries collectively owned a 75% ownership interest in us (a 73% limited partner interest and a 2% general partner interest), together with 100% of our incentive distribution rights, and the remaining 25% limited partner interest was publicly owned.

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, 2016, 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.

Enbridge and its affiliates are solely responsible for providing the employees and other personnel necessary to conduct our operations. Our costs of doing business have been reflected in our financial accounting records for the periods presented. These costs include direct charges and allocations from Enbridge and its affiliates for business services, such as payroll, accounts payable and facilities management; corporate services, such as finance and accounting, legal, human resources, investor relations, public and regulatory policy, and senior executives; and pension and other post-retirement benefit costs.

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.

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2. Business Segments

We manage our business in two reportable segments: U.S. Transmission and Liquids. The remainder of our business operations is presented as “Other,” and consists of certain corporate costs.

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

The U.S. Transmission segment provides interstate transmission, storage and gathering of natural gas. Substantially all of our operations are subject to the Federal Energy Regulatory Commission (FERC) and the Department of Transportation’s (DOT’s) rules and regulations. Our investments in Gulfstream Natural Gas System, LLC (Gulfstream), Southeast Supply Header, LLC (SESH) and Steckman Ridge, LP are included in U.S. Transmission.

The Liquids segment provides transportation of crude oil. The Express-Platte pipeline system (Express-Platte) is a crude oil pipeline system that connects Canadian and U.S. producers to refineries in the U.S. Rocky Mountain and Midwest regions. These operations are primarily subject to the rules and regulations of the FERC and the National Energy Board (NEB).

Our reportable segments offer different products and services and are managed separately as business units. Management evaluates segment performance based on earnings before interest, taxes, and depreciation and amortization (EBITDA). Cash, cash equivalents and investments are managed centrally, so the gains and losses on foreign currency remeasurement, 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.

Business Segment Data

Condensed Consolidated Statements of Operations	Total Operating Revenues		Depreciation and Amortization		Segment EBITDA/Consolidated Earnings Before Income Taxes
	(in millions)
Three Months Ended March 31, 2017
U.S. Transmission	$	596	$	77	$	479
Liquids	104		8		66
Total reportable segments	700		85		545
Other	—		—		(46		)
Depreciation and amortization	—				85
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	700	$	85	$	359
Three Months Ended March 31, 2016
U.S. Transmission	$	538	$	70	$	411
Liquids	86		7		56
Total reportable segments	624		77		467
Other	—		—		(20		)
Depreciation and amortization	—		—		77
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	624	$	77	$	315

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3. Net Income Per Limited Partner Unit and Cash Distributions

The following table presents our net income per limited partner unit calculations:

	Three Months Ended March 31,
	2017		2016
	(in millions, except per unit amounts)
Net income—controlling interests	$	317	$	298
Less:
General partner’s interest in net income attributable to general partner units—2%	6		6
General partner’s interest in net income attributable to incentive distribution rights	83		63
Limited partners’ interest in net income attributable to common units	$	228	$	229
Weighted average limited partner units outstanding—basic and diluted	309		285
Net income per limited partner unit—basic and diluted	$	0.74	$	0.80

Our partnership agreement requires that, within 60 days after the end of each quarter, we distribute all of our Available Cash, as defined, to unitholders of record on the applicable record date.

Available Cash. Available Cash, for any quarter, consists of all cash and cash equivalents on hand at the end of that quarter:

• less the amount of cash reserves established by the general partner to:

• provide for the proper conduct of business,

• comply with applicable law, any debt instrument or other agreement, or

• provide funds for minimum quarterly distributions to the unitholders and to the general partner for any one or more of the next four quarters,

• plus, if the general partner so determines, all or a portion of cash and cash equivalents on hand on the date of determination of Available Cash for the quarter.

Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Common Unit Amount	Common Unitholders		General Partner
Minimum Quarterly Distribution	$0.30	98	%	2	%
First Target Distribution	above $0.30 up to $0.345	98	%	2	%
Second Target Distribution	above $0.345 up to $0.375	85	%	15	%
Third Target Distribution	above $0.375 up to $0.45	75	%	25	%
Thereafter	above $0.45	50	%	50	%

To the extent these incentive distributions are made to the general partner, there will be more Available Cash proportionately allocated to our general partner than to holders of common units. A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017 and is payable on May 26, 2017 to unitholders of record at the close of business on May 15, 2017.

There is a reduction in the aggregate quarterly distributions, if any, to Spectra Energy, (as indirect holder of incentive distribution rights), by $4 million per quarter for a period of 12 consecutive quarters commencing with the quarter ending on December 31, 2015 through the quarter ending on September 30, 2018. The reduction of distributions is a result of the sale of our interests in DCP Sand Hills Pipeline, LLC (Sand Hills) and DCP Southern Hills Pipeline, LLC (Southern Hills) to Spectra Energy in October 2015.

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4. Variable Interest Entities

Sabal Trail. In April 2016, NextEra Energy, Inc. (NextEra) purchased a 9.5% interest in Sabal Trail Transmission, LLC (Sabal Trail) from us. See Note 5 for additional information related to this transaction. As of March 31, 2017, we owned a 50% interest in Sabal Trail, a joint venture that is constructing a natural gas pipeline to transport natural gas to Florida. Sabal Trail is a variable interest entity (VIE) due to insufficient equity at risk to finance its activities. We determined that we are the primary beneficiary because we direct the activities of Sabal Trail that most significantly impact its economic performance and we consolidate Sabal Trail in our financial statements. The current estimate of the total remaining construction cost is approximately $0.7 billion.

The following summarizes assets and liabilities for Sabal Trail:

Condensed Consolidated Balance Sheets	March 31, 2017		December 31, 2016
	(in millions)
Assets
Current assets	$	225	$	165
Net property, plant and equipment	2,552		1,942
Regulatory assets and deferred debits	100		79
Total Assets	$	2,877	$	2,186
Liabilities and Equity
Current liabilities	$	285	$	239
Equity	2,592		1,947
Total Liabilities and Equity	$	2,877	$	2,186

Nexus. We own a 50% interest in Nexus Gas Transmission, LLC (Nexus), a joint venture that is constructing a natural gas pipeline from Ohio to Michigan and continuing on to Ontario, Canada. Nexus is a VIE due to insufficient equity at risk to finance its activities. We determined that we are not the primary beneficiary because the power to direct the activities of Nexus that most significantly impact its economic performance is shared. We account for Nexus under the equity method. Our maximum exposure to loss is $1.0 billion. We have an investment in Nexus of $435 million and $356 million as of March 31, 2017 and December 31, 2016, respectively, classified as Investments in and Loans to Unconsolidated Affiliates on our Condensed Consolidated Balance Sheets.

In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of Nexus. See Note 11 for further discussion of the guarantee arrangement.

5. Intangible Asset

During the first quarter of 2016 we entered into a project coordination agreement (PCA) with NextEra, Duke Energy Corporation and Williams Partners L.P. In accordance with the agreement, payments will be made, based on our proportional ownership interest in the Sabal Trail project, as certain milestones of the project are met. During the first quarter of 2016, the first milestone was achieved and paid, consisting of $48 million.

In April 2016, NextEra purchased an additional 9.5% interest in Sabal Trail, reducing our ownership interest in Sabal Trail to 50%. Upon purchase of the additional ownership interest, NextEra reimbursed us $8 million for NextEra’s proportional share of the first milestone payment, which reduced our total milestone payments to $40 million as of June 2016.

During the third quarter of 2016, the second milestone was achieved and paid, consisting of an additional payment of $40 million, for total milestone payments of $80 million as of March 31, 2017 . Both payments are classified as Cash Flows from Investing Activities — Purchase of Intangible, Net. This PCA is an intangible asset and is classified as Investments and Other Assets — Other on our Condensed Consolidated Balance Sheet. The intangible asset will be amortized over a period of 25 years beginning at the time of in-service of Sabal Trail, which is expected to occur during the second quarter of 2017.

6. Marketable Securities and Restricted Funds

We routinely invest excess cash and various restricted balances in securities such as commercial paper, corporate debt securities, and other money market securities in the United States, as well as equity securities in Canada. We do not purchase marketable securities for speculative purposes, therefore we do not have any securities classified as trading securities. While we

13

do not routinely sell marketable securities prior to their scheduled maturity dates, some of our investments may be held and restricted for the purposes of funding future capital expenditures and NEB regulatory requirements, 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. We had $2 millionand$10 million of AFS securities classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These investments include $2 million and $1 million of restricted funds held and collected from customers for Canadian pipeline abandonment in accordance with the NEB's regulatory requirements, as of March 31, 2017 and December 31, 2016, respectively, as well as $9 million of restricted funds related to certain construction projects as of December 31, 2016.

At March 31, 2017, the weighted-average contractual maturity of outstanding AFS securities was less than one year.

There were no material gross unrecognized holding gains or losses associated with investments in AFS securities at March 31, 2017 or December 31, 2016.

HTM Securities. All of our HTM securities are restricted funds. We had $4 million and $3 million of money market securities classified as Current Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These securities are restricted pursuant to certain Express-Platte debt agreements.

At March 31, 2017, the weighted-average contractual maturity of outstanding HTM securities was less than one year.

There were no material gross unrecognized holding gains or losses associated with investments in HTM securities at March 31, 2017 or December 31, 2016.

Other Restricted Funds. In addition to the AFS and HTM securities that were restricted funds as described above, we had other restricted funds totaling $3 million and $5 million classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016, respectively. These restricted funds are related to certain construction projects.

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

7. Debt and Credit Facility

Available Credit Facility and Restricted Debt Covenants

	Expiration Date	Total Credit Facility Capacity		Commercial Paper Outstanding at March 31, 2017		Available Credit Facility Capacity
		(in millions)
Spectra Energy Partners, LP	2021	$	2,500	$	1,051	$	1,449

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facility. As of March 31, 2017, there were no letters of credit issued or revolving borrowings outstanding under the credit facility.

Our credit agreements contain various covenants, including the maintenance of a consolidated leverage ratio, as defined in the agreements. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of March 31, 2017, 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 our other significant indebtedness or other significant indebtedness of some of our 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.

As noted above, the terms of our credit agreements require us to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the agreement, of 5.0 to 1 or less. As of March 31, 2017, this ratio was 4.1 to 1.

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8. Fair Value Measurements

The following presents, for each of the fair value hierarchy levels, assets that are measured at fair value on a recurring basis as of March 31, 2017 and December 31, 2016:

Description	Condensed Consolidated Balance Sheet Caption	March 31, 2017
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	199	$	—	$	199	$	—
Canadian equity securities	Investments and other assets — other	2		2		—		—
Interest rate swaps	Investments and other assets — other	8		—		8		—
Total Assets		$	209	$	2	$	207	$	—

Description	Condensed Consolidated Balance Sheet Caption	December 31, 2016
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	145	$	—	$	145	$	—
Corporate debt securities	Investments and other assets — other	9		—		9		—
Canadian equity securities	Investments and other assets — other	1		1		—		—
Interest rate swaps	Investments and other assets — other	9		—		9		—
Total Assets		$	164	$	1	$	163	$	—

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.

Level 3 Valuation Techniques

Level 3 valuation techniques 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.

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.

	March 31, 2017				December 31, 2016
	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)	6,662		6,826		6,672		6,855

________ 

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

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

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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, commercial paper and short-term money market securities 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 three months ended March 31,2017 and 2016, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

9. Risk Management and Hedging Activities

Changes in interest rates expose us to risk as a result of our issuance of variable and fixed-rate debt and commercial paper. We are exposed to foreign currency risk from the Canadian portion of Express-Platte. 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 exposures. For interest rate derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative as well as the offsetting loss or gain on the hedged item attributable to the hedged risk is recognized in the Condensed Consolidated Statements of Operations. There were no significant amounts of gains or losses recognized in net income during the three months ended March 31, 2017.

At March 31, 2017, we had “pay floating — receive fixed” interest rate swaps outstanding with a total notional amount of $900 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:

	March 31, 2017						December 31, 2016
	Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount		Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount
Description	(in millions)
Assets	$	8	$	—	$	8	$	9	$	—	$	9

10. Commitments and Contingencies

Environmental

We are subject to various federal, state and local laws and regulations 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.

Litigation

Litigation and Legal Proceedings. We are involved in legal, tax and regulatory proceedings in various forums arising in the ordinary course of business, including matters regarding contract and payment claims, some of which involve substantial monetary amounts. We have insurance coverage for certain of these losses should they be incurred. We believe that the final

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disposition of these proceedings will not have a material effect on our consolidated results of operations, financial position or cash flows.

Legal costs related to the defense of loss contingencies are expensed as incurred. We had no material reserves for legal matters recorded as of March 31, 2017 or December 31, 2016 related to litigation.

11. Guarantees

We have various financial guarantees which are issued in the normal course of business. We enter into these arrangements to facilitate a commercial transaction with a third party by enhancing the value of the transaction to the third party. To varying degrees, these guarantees involve elements of performance and credit risk, which are not included on our Condensed Consolidated Balance Sheets. The possibility of having to perform under these guarantees is largely dependent upon future operations of various subsidiaries, investees and other third parties, or the occurrence of certain future events.

In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of an equity method investee. These guarantees were issued to enable the equity method investee to enter into long-term transportation contracts with the third party. While the likelihood is remote, the maximum potential amount of future payments we could have been required to make as of March 31, 2017 was $61 million. These performance guarantees expire in 2032.

As of March 31, 2017, the amounts recorded for the guarantees described above are not material, both individually and in the aggregate.

12. Issuances of Common Units

During the three months ended March 31, 2017, we issued 0.8 million common units to the public under our at-the-market program, and approximately 17,000 general partner units to our general partner in order for it to maintain a 2% general partner interest. Total net proceeds were $39 million, including approximately $1 million of proceeds from our general partner.

13. New Accounting Pronouncements

In October 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control,” to amend the consolidation guidance on how a reporting entity that is the single decision maker of a VIE should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-07, “Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which simplifies the embedded derivative analysis for debt instruments containing contingent call or put options. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies the hedge accounting impact when there is a change in one of the counterparties to the derivative contract (i.e. novation). We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In July 2015, the FASB issued ASU No. 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which simplifies the subsequent measurement of inventory by requiring inventory to be measured at the lower of cost and net realizable value. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In February 2017, the FASB issued ASU No. 2017-05, “Other Income—Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales

17

of Nonfinancial Assets,”to clarify the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The ASU also clarifies the scope provisions of nonfinancial assets, how to allocate consideration to each distinct asset, and amends the guidance for derecognition of a distinct nonfinancial asset in partial sale transactions. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We are currently evaluating this ASU and its potential impact on us.

In January 2017, the FASB issued ASU No. 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment,” to simplify the subsequent measurement of goodwill. Under the new guidance, goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In January 2017, the FASB issues ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” to add guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (disposals) of assets or businesses. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In November 2016, the FASB issued ASU No. 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash,” to address the diversity in the classification and presentation of changes in restricted cash and restricted cash equivalents on the statement of cash flows. The update requires that restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In August 2016, the FASB issued ASU No. 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments,” to provide guidance on specific cash flow issues with the objective of reducing the existing diversity in practice. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” to provide financial statement users with more useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. Current treatment uses the incurred loss methodology for recognizing credit losses that delays the recognition until it is probable a loss has been incurred. The amendment adds a new impairment model, known as the current expected credit loss model that is based on expected losses rather than incurred losses. Under the new guidance, an entity recognizes as an allowance its estimate of expected credit losses, which the FASB believes will result in more timely recognition of such losses. This ASU is effective for us on January 1, 2020. We are currently evaluating this ASU and its potential impact on us.

In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842),” to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on our consolidated statements of financial position and disclosing additional key information about lease agreements. This ASU is effective for us on January 1, 2019. We are currently evaluating this ASU and its potential impact on us.

In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” to amend the classification and measurement of financial instruments. Changes primarily affect the accounting for equity investments, financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. This ASU is effective for us on January 1, 2018. Early adoption is not permitted. We are currently evaluating this ASU and its potential impact on us.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” to significantly enhance consistency and comparability of revenue recognition practices across entities and industries. The new standard establishes a single, principles-based five-step model to be applied to all contracts with customers and introduces new and enhanced disclosure requirements. Since its release, the FASB has issued multiple amendments clarifying and/or amending ASU No. 2014-09. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We have substantially completed a review of contracts with customers in relation to the requirements of ASU No. 2014-09. While we have not identified any material difference in the amount or timing of revenue recognition for the categories we have reviewed to date, our evaluation is not complete and we have not concluded on the overall impacts of adopting this standard. In addition, we are in the process of implementing appropriate changes to our business processes, systems and controls to support the recognition and disclosure requirements under the new standard.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

INTRODUCTION

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the accompanying Condensed Consolidated Financial Statements.

EXECUTIVE OVERVIEW

For the three months ended March 31, 2017 and 2016, we reported net income from controlling interests of $317 million and $298 million, respectively.

The highlights for the three months ended March 31, 2017 included increased earnings driven by expansion, mainly on Algonquin Gas Transmission, LLC (Algonquin) and Texas Eastern Transmission, LP (Texas Eastern), higher transportation revenues due to higher volumes of heavy oil on the Express pipeline and expansion revenues from the Express Enhancement project placed into service in October 2016, partially offset by merger-related severance costs.

For the three months ended March 31, 2017 and 2016, distributable cash flow was $356 million and $371 million, respectively.

A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017 and is payable on May 26, 2017. We intend to increase our quarterly distribution by one and a quarter cents per unit each quarter through 2017. Our Board of Directors evaluates each distribution decision within the confines of the Partnership agreement and based on an assessment of growth in distributable cash flow.

For the three months ended March 31, 2017, we had $808 million of capital and investment expenditures. We currently project $2.6 billion of capital and investment expenditures for the full year, including expansion capital expenditures of $2.3 billion. These projections exclude contributions from noncontrolling interests.

We are committed to an investment-grade balance sheet and continued prudent financial management of our capital structure. Therefore, financing growth activities will continue to be based on our strong and growing fee-based earnings and cash flows, the issuances of debt and equity securities as well as return of capital from joint venture asset-level financings. As of March 31, 2017, we have access to a $2.5 billion revolving credit facility which is used principally as a back-stop for our commercial paper program.

On February 27, 2017, Enbridge and Spectra Energy completed the Merger pursuant to which Spectra Energy merged with and into a direct, wholly owned subsidiary of Enbridge, with Spectra Energy continuing as the surviving corporation and a wholly owned subsidiary of Enbridge, and each outstanding share of common stock of Spectra Energy was automatically converted into, and became exchangeable for, 0.984 of Enbridge common share. As a result of the Merger, we became an indirect subsidiary of Enbridge through Enbridge’s ownership of Spectra Energy.

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RESULTS OF OPERATIONS

	Three Months Ended March 31,
	2017		2016
	(in millions)
Operating revenues	$	700	$	624
Operating expenses	368		300
Operating income	332		324
Earnings from equity investments	38		27
Other income and expenses, net	45		20
Interest expense	56		56
Earnings before income taxes	359		315
Income tax expense	5		4
Net income	354		311
Net income—noncontrolling interests	37		13
Net income—controlling interests	$	317	$	298

Operating Revenues. The $76 million increase was driven mainly by:

• revenues from expansion projects, primarily on Algonquin and Texas Eastern, and

• higher transportation revenues due to higher volumes of heavy oil on the Express pipeline and the Express Enhancement expansion project placed into service in October 2016, partially offset by

• lower recoveries of electric power and other costs passed through to gas transmission customers.

Operating Expenses. The $68 million increase was driven mainly by:

• merger-related severance costs and

• higher costs related to expansion, partially offset by

• lower electric power and other costs passed through to gas transmission customers.

Other Income and Expenses, Net.The $25 million increase was mainly attributable to higher allowance for funds used during construction (AFUDC) due to higher capital spending on expansion projects.

Segment Results

Management evaluates segment performance based on EBITDA. Cash, cash equivalents and investments are managed centrally, so the gains and losses on foreign currency remeasurement, and interest and dividend income, are excluded from the segments’ EBITDA. We consider segment EBITDA to be a good indicator of each segment’s operating performance from its continuing operations, as it represents the results of our operations without regard to financing methods or capital structures. 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.

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Segment EBITDA is summarized in the following table. Detailed discussions follow.

EBITDA by Business Segment

	Three Months Ended March 31,
	2017			2016
	(in millions)
U.S. Transmission	$	479		$	411
Liquids	66			56
Total reportable segment EBITDA	545			467
Other	(46		)	(20		)
Total reportable segment and other EBITDA	499			447
Depreciation and amortization	85			77
Interest expense	56			56
Interest income and other	1			1
Earnings before income taxes	$	359		$	315

The amounts discussed below are after eliminating intercompany transactions.

U.S. Transmission

	Three Months Ended March 31,
	2017		2016		Increase (Decrease)
	(in millions)
Operating revenues	$	596	$	538	$	58
Operating expenses
Operating, maintenance and other	200		172		28
Other income and expenses	83		45		38
EBITDA	$	479	$	411	$	68

Operating Revenues. The $58 million increase was driven by:

• a $62 million increase due to expansion, primarily on Algonquin and Texas Eastern, and

• a $2 million increase in storage revenues due to new contracts at higher rates, partially offset by

• a $5 million decrease in recoveries of electric power and other costs passed through to gas transmission customers and

• a $3 million decrease in natural gas transportation revenues mainly from firm transportation on Algonquin and Texas Eastern.

Operating Expenses.The $28 million increase was driven by:

• $18 million of merger-related severance costs,

• a $12 million increase in costs related to expansion and

• a $2 million increase due to pipeline inspection and repair costs related to the 2016 Texas Eastern pipeline incident, partially offset by

• a $5 million decrease in electric power and other costs passed through to gas transmission customers.

Other Income and Expenses.The $38 million increase was mainly due to higher AFUDC resulting from higher capital spending on expansion projects.

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Liquids

	Three Months Ended March 31,
	2017			2016		Increase (Decrease)
	(in millions)
Operating revenues	$	104		$	86	$	18
Operating expenses
Operating, maintenance and other	37			31		6
Other income and expenses	(1		)	1		(2		)
EBITDA	$	66		$	56	$	10
Express pipeline revenue receipts, MBbl/d (a)	271			233		38
Platte PADD II deliveries, MBbl/d	146			124		22

_______

(a)    Thousand barrels per day.

Operating Revenues. The $18 million increase in operating revenues was driven by:

• a $9 million increase in transportation revenues as a result of higher Express pipeline volumes of heavy oil and

• a $7 million increase in transportation revenues due to the Express Enhancement expansion project placed into service in October 2016.

Operating Expenses. The $6 million increase in operating expenses was mainly driven by:

• a $3 million increase in power costs primarily due to higher usage and

• $2 million of merger-related severance costs.

Other

	Three Months Ended March 31,
	2017			2016			Increase (Decrease)
	(in millions)
Operating expenses	$	46		$	20		$	26
EBITDA	$	(46	)	$	(20	)	$	(26	)

Operating Expenses. The $26 million increase primarily reflects merger-related severance costs.

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Distributable Cash Flow

We define Distributable Cash Flow as EBITDA plus

• distributions from equity investments,

• other non-cash items affecting net income, less

• earnings from equity investments,

• interest expense,

• equity AFUDC,

• net cash paid for income taxes,

• distributions to noncontrolling interests, and

• maintenance capital expenditures.

Distributable Cash Flow does not reflect changes in working capital balances. Distributable Cash Flow should not be viewed as indicative of the actual amount of cash that we plan to distribute for a given period.

Distributable Cash Flow is the primary financial measure used by our management and by external users of our financial statements to assess the amount of cash that is available for distribution.

Distributable Cash Flow is a non-GAAP measure and should not be considered an alternative to Net Income, Operating Income, cash from operations or any other measure of financial performance or liquidity presented in accordance with GAAP. Distributable Cash Flow excludes some, but not all, items that affect Net Income and Operating Income and these measures may vary among other companies. Therefore, Distributable Cash Flow as presented may not be comparable to similarly titled measures of other companies.

Significant drivers of variances in Distributable Cash Flow between the periods presented are substantially the same as those previously discussed under Results of Operations. Other drivers include the timing of certain cash outflows, such as capital expenditures for maintenance.

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Reconciliation of Net Income to Non-GAAP “Distributable Cash Flow”

	Three Months Ended March 31,
	2017			2016
	(in millions)
Net income	$	354		$	311
Add:
Interest expense	56			56
Income tax expense	5			4
Depreciation and amortization	85			77
Foreign currency (gain) loss	—			(1		)
Less:
Third party interest income	1			—
EBITDA	499			447
Add:
Earnings from equity investments	(38		)	(27		)
Distributions from equity investments	38			65
Other	1			2
Less:
Interest expense	56			56
Equity AFUDC	45			17
Net cash paid for income taxes	5			1
Distributions to noncontrolling interests	12			7
Maintenance capital expenditures	26			35
Distributable Cash Flow	$	356		$	371

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LIQUIDITY AND CAPITAL RESOURCES

As of March 31, 2017, we had negative working capital of $1,514 million. This balance includes commercial paper liabilities totaling $1,051 million and current maturities of long-term debt of $415 million. We will rely upon cash flows from operations, including cash distributions received from our equity affiliates, and various financing transactions, which may include debt and/or equity issuances, to fund our liquidity and capital requirements for the next 12 months. We have access to a revolving credit facility, with available capacity of $1,449 million at March 31, 2017. This facility is used principally as a back-stop for our commercial paper program, which is used to manage working capital requirements and for temporary funding of capital expenditures. We expect to be self-funding and plan to continue to pursue expansion opportunities over the next several years. Capital resources may continue to include commercial paper, short-term borrowings under our current credit facility and possibly securing additional sources of capital including debt and/or equity as well as return of capital from joint venture asset-level financings. See Note 7 of Notes to Condensed Consolidated Financial Statements for a discussion of the available credit facility and Financing Cash Flows and Liquidity for a discussion of effective shelf registrations.

Cash Flow Analysis

The following table summarizes the changes in cash flows for each of the periods presented:

	Three Months Ended March 31,
	2017			2016
	(in millions)
Net cash provided by (used in):
Operating activities	$	364		$	297
Investing activities	(788		)	(508		)
Financing activities	490			257
Net increase in cash and cash equivalents	66			46
Cash and cash equivalents at beginning of the period	216			168
Cash and cash equivalents at end of the period	$	282		$	214

Operating Cash Flows

Net cash provided by operating activities increased $67 million to $364 million in the three months ended March 31, 2017 compared to the same period in 2016, driven mainly by higher earnings and changes in working capital.

Investing Cash Flows

Net cash used in investing activities increased $280 million to $788 million in the three months ended March 31, 2017 compared to the same period in 2016. The change was mainly driven by increased capital and investment expenditures.

Capital and Investment Expenditures by Business Segment

	Three Months Ended March 31,
	2017		2016
	(in millions)
U.S. Transmission	$	802	$	479
Liquids	6		16
Total consolidated	$	808	$	495

Capital and investment expenditures for the three months endedMarch 31, 2017 consisted of $782 million for expansion projects and $26 million for maintenance and other projects.

We project 2017 capital and investment expenditures of approximately $2.6 billion, consisting of $2.3 billion of expansion capital expenditures and $0.3 billion for maintenance and upgrades of existing plants, pipelines and infrastructure to serve growth. These projections exclude contributions from noncontrolling interests.

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Financing Cash Flows and Liquidity

Net cash provided by financing activities increased $233 million to $490 million in the three months ended March 31, 2017 compared to the same period in 2016. The change was mainly driven by:

• a $195 million increase in contributions from noncontrolling interests and

•a $147 million increase in issuances of commercial paper, partially offset by

• a $51 million increase in distributions to partners and

• a $43 million decrease in proceeds from issuances of units.

During the three months ended March 31, 2017, we issued 0.8 million common units to the public under our at-the-market program and approximately 17,000 general partner units to our general partner in order for it to maintain a 2% general partner interest. Total net proceeds were $39 million, including approximately $1 million of proceeds from Spectra Energy. The net proceeds were used for general partnership purposes, which may have included debt repayment, capital expenditures and/or additions to working capital. In 2017, we have issued 1 million common units to the public under our at-the-market program and approximately 21,000 general partner units to our general partner in order for it to maintain a 2% general partner interest, for total net proceeds of approximately $48 million, including $1 million of proceeds from Spectra Energy.

Available Credit Facility and Restrictive Debt Covenants. See Note 7 of Notes to Condensed Consolidated Financial Statements for a discussion of the available credit facility and related financial and other covenants.

Cash Distributions. A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017, payable on May 26, 2017, representing the thirty-eighth consecutive quarterly increase.

Other Financing Matters. We have an effective shelf registration statement on file with the Securities and Exchange Commission (SEC) to register the issuance of unspecified amounts of limited partner common units and various debt securities and another registration statement on file with the SEC to register the issuance of $1 billion, in the aggregate, of limited partner units over time. This registration has $321 million available as of March 31, 2017.

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OTHER ISSUES

New Accounting Pronouncements. See Note 13 of Notes to Condensed Consolidated Financial Statements for discussion.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Our exposure to market risk is described in Item 7A of our Annual Report on Form 10-K, for the year ended December 31, 2016. We believe our exposure to market risk has not changed materially since then.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports we file or submit under the Securities Exchange Act of 1934 (Exchange Act) is recorded, processed, summarized, and reported, within the time periods specified by the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by us in the reports we file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of the management of Spectra Energy Partners (DE) GP, LP (our General Partner), including the Chief Executive Officer and Chief Financial Officer, we have evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2017, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

Under the supervision and with the participation of the management of our General Partner, including the Chief Executive Officer and Chief Financial Officer, we have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended March 31, 2017 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

27

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

We have no material pending legal proceedings that are required to be disclosed hereunder. For information regarding other legal proceedings and environmental matters, see Note 10 of Notes to Condensed Consolidated Financial Statements, which information is incorporated by reference into this Part II.

Item 1A. Risk Factors.

In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016, which could materially affect our financial condition or future results. There have been no material changes to those risk factors.

Item 5. Other Information.

On May 4, 2017, Stephen J. Neyland, 49, was appointed as the Vice President—Finance of Spectra Energy Partners GP, LLC, the general partner of Spectra Energy Partners (DE) GP, LP, which is the general partner of Spectra Energy Partners, LP (the Partnership).  Mr. Neyland also serves as Vice President—Finance of Enbridge Energy Partners, L.P.’s general partner and of Enbridge Energy Management, L.L.C. (collectively, the Enbridge Affiliates) since October 2010. Mr. Neyland previously served the Enbridge Affiliates as Controller from 2006 to 2010, Controller—Natural Gas from January 2005, Assistant Controller from May 2004 to January 2005 and in other managerial roles in finance and accounting from December 2001 to May 2004. Prior to joining Enbridge, Mr. Neyland was Controller of Koch Midstream Services from 1999 to 2001.  Mr. Neyland does not have an employment contract with the Partnership. The Partnership does not directly employ the officers of the General Partner and does not have control over their compensation.

Item 6. Exhibits.

Any agreements included as exhibits to this Form 10-Q may contain representations and warranties by each of the parties to the applicable agreement. These representations and warranties have been made solely for the benefit of the other parties to the applicable agreement and:

• were not intended to be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate;

• may have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement;

• may apply contract standards of “materiality” that are different from “materiality” under the applicable securities laws; and

• were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement.

We acknowledge that, notwithstanding the inclusion of the foregoing cautionary statements, we are responsible for considering whether additional specific disclosures of material information regarding material contractual provisions are required to make the statements in this Form 10-Q not misleading.

28

(a) Exhibits
Exhibit Number
*31.1	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*32.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*32.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*101.INS	XBRL Instance Document.
*101.SCH	XBRL Taxonomy Extension Schema.
*101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
*101.DEF	XBRL Taxonomy Extension Definition Linkbase.
*101.LAB	XBRL Taxonomy Extension Label Linkbase.
*101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

* Filed herewith

The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% of the total assets of the registrant and its subsidiaries on a consolidated basis. The registrant agrees, upon request of the Securities and Exchange Commission, to furnish copies of any or all of such instruments to it.

29

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	SPECTRA ENERGY PARTNERS, LP
	By:	Spectra Energy Partners (DE) GP, LP, its general partner
	By:	Spectra Energy Partners GP, LLC, its general partner
Date: May 10, 2017	By:	/S/    William T. Yardley
		William T. Yardley President and Chairman of the Board
Date: May 10, 2017	By:	/S/    Stephen J. Neyland
		Stephen J. Neyland Vice President—Finance

30

EX-31.1

EXHIBIT 31.1

CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, William T. Yardley, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Spectra Energy Partners, LP;

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

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

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

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

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

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

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

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

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

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

Date: May 10, 2017	/s/ William T. Yardley
	William T. Yardley President and Chairman of the Board Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-31.2

EXHIBIT 31.2

CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Stephen J. Neyland, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Spectra Energy Partners, LP;

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

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

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

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

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

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

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

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

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

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

Date: May 10, 2017	/s/ Stephen J. Neyland
	Stephen J. Neyland Vice President—Finance Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Spectra Energy Partners, LP on Form 10-Q for the period ending March 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William T. Yardley, President and Chairman of the Board of Spectra Energy Partners GP, LLC, general partner of Spectra Energy Partners (DE) GP, LP, general partner of Spectra Energy Partners, LP, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Spectra Energy Partners, LP.

Date: May 10, 2017	/s/ William T. Yardley
	William T. Yardley President and Chairman of the Board Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-32.2

EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Spectra Energy Partners, LP on Form 10-Q for the period ending March 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Stephen J. Neyland, VicePresident—Finance of Spectra Energy Partners GP, LLC, general partner of Spectra Energy Partners (DE) GP, LP, general partner of Spectra Energy Partners, LP, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Spectra Energy Partners, LP.

Date: May 10, 2017	/s/ Stephen J. Neyland
	Stephen J. Neyland Vice President—Finance Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2017 shares
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Trading Symbol	SEP
Entity Registrant Name	SPECTRA ENERGY PARTNERS, LP
Entity Central Index Key	0001394074
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	309,242,850
Entity General Partner, Units Outstanding	6,311,079

XML

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating Revenues
Transportation of natural gas	$ 538	$ 484
Transportation of crude oil	101	86
Storage of natural gas and other	61	54
Total operating revenues	700	624
Operating Expenses
Operating, maintenance and other	227	179
Depreciation and amortization	85	77
Property and other taxes	56	44
Total operating expenses	368	300
Operating Income	332	324
Other Income and Expenses
Earnings from equity investments	38	27
Other income and expenses, net	45	20
Total other income and expenses	83	47
Interest Expense	56	56
Earnings Before Income Taxes	359	315
Income Tax Expense	5	4
Net Income	354	311
Net Income—Noncontrolling Interests	37	13
Net Income—Controlling Interests	317	298
Calculation of Limited Partners’ Interest in Net Income:
Net Income—Controlling Interests	317	298
Less: General partner’s interest in net income	89	69
Limited partners’ interest in net income	$ 228	$ 229
Weighted average limited partner units outstanding—basic and diluted	309	285
Net income per limited partner unit—basic and diluted	$ 0.74	$ 0.80
Distributions paid per limited partner unit	$ 0.68875	$ 0.63875

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Net Income	$ 354	$ 311
Other comprehensive income:
Foreign currency translation adjustments	1	11
Total other comprehensive income	1	11
Total Comprehensive Income	355	322
Less: Comprehensive Income—Noncontrolling Interests	37	13
Comprehensive Income—Controlling Interests	$ 318	$ 309

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current Assets
Cash and cash equivalents	$ 282	$ 216
Receivables, net	339	380
Inventory	40	40
Fuel tracker	7	6
Other	17	18
Total current assets	685	660
Investments and Other Assets
Investments in and loans to unconsolidated affiliates	1,200	1,127
Goodwill	3,234	3,234
Other	98	108
Total investments and other assets	4,532	4,469
Property, Plant and Equipment
Cost	20,735	19,958
Less accumulated depreciation and amortization	3,940	3,866
Net property, plant and equipment	16,795	16,092
Regulatory Assets and Deferred Debits	409	385
Total Assets	22,421	21,606
Current Liabilities
Accounts payable	486	441
Commercial paper	1,051	574
Taxes accrued	59	76
Interest accrued	43	79
Current maturities of long-term debt	415	416
Other	145	193
Total current liabilities	2,199	1,779
Long-term Debt	6,212	6,223
Deferred Credits and Other Liabilities
Deferred income taxes	43	42
Regulatory and other	154	158
Total deferred credits and other liabilities	197	200
Commitments and Contingencies
Partners’ Capital
Common units (309.2 million and 308.4 million units issued and outstanding at March 31, 2017 and December 31, 2016, respectively)	11,703	11,650
General partner units (6.3 million units issued and outstanding at March 31, 2017 and December 31, 2016)	481	452
Accumulated other comprehensive loss	(44)	(45)
Total partners’ capital	12,140	12,057
Noncontrolling interests	1,673	1,347
Total equity	13,813	13,404
Total Liabilities and Equity	$ 22,421	$ 21,606

XML

Condensed Consolidated Balance Sheets (Parenthetical) (Unaudited) - shares shares in Millions	Mar. 31, 2017	Dec. 31, 2016
Common units, units issued	309.2	308.4
Common units, units outstanding	309.2	308.4
General partner units, units issued	6.3	6.3
General partner units, units outstanding	6.3	6.3

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 354	$ 311
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	85	79
Deferred income tax expense	1	1
Earnings from equity investments	(38)	(27)
Distributions from equity investments	27	26
Other	(65)	(93)
Net cash provided by operating activities	364	297
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(738)	(468)
Investments in and loans to unconsolidated affiliates	(70)	(27)
Purchase of intangible, net	0	(48)
Distributions from equity investments	11	39
Purchases of held-to-maturity securities	(4)	(11)
Proceeds from sales and maturities of held-to-maturity securities	3	3
Purchases of available-for-sale securities	(68)	(161)
Proceeds from sales and maturities of available-for-sale securities	76	163
Other changes in restricted funds	2	4
Other	0	(2)
Net cash used in investing activities	(788)	(508)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(10)	0
Net increase in commercial paper	477	330
Distributions to noncontrolling interests	(12)	(7)
Contributions from noncontrolling interests	290	95
Proceeds from the issuances of units	39	82
Distributions to partners	(294)	(243)
Net cash provided by financing activities	490	257
Net increase in cash and cash equivalents	66	46
Cash and cash equivalents at beginning of period	216	168
Cash and cash equivalents at end of period	282	214
Supplemental Disclosures
Property, plant and equipment non-cash accruals	$ 261	$ 142

XML

Condensed Consolidated Statements of Equity (Unaudited) - USD ($) $ in Millions	Total	Limited Partners Common	General Partner	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance at Dec. 31, 2015	$ 11,346	$ 10,527	$ 336	$ (50)	$ 533
Increase (Decrease) in Equity
Net income	311	229	69		13
Other comprehensive income (loss)	11			11
Attributed deferred tax benefit	12		10		2
Issuances of units	82	80	2
Distributions to partners	(243)	(182)	(61)
Contributions from noncontrolling interests	95				95
Distributions to noncontrolling interests	(7)				(7)
Ending balance at Mar. 31, 2016	11,607	10,654	356	(39)	636
Beginning balance at Dec. 31, 2016	13,404	11,650	452	(45)	1,347
Increase (Decrease) in Equity
Net income	354	228	89		37
Other comprehensive income (loss)	1			1
Attributed deferred tax benefit	31		20		11
Issuances of units	39	38	1
Distributions to partners	(294)	(213)	(81)
Contributions from noncontrolling interests	290				290
Distributions to noncontrolling interests	(12)				(12)
Ending balance at Mar. 31, 2017	$ 13,813	$ 11,703	$ 481	$ (44)	$ 1,673

XML

General

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

General

General

The terms “we,” “our,” “us” and “Spectra Energy Partners” as used in this report refer collectively to Spectra Energy Partners, LP 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 Partners.

Nature of Operations. Spectra Energy Partners, through its subsidiaries and equity affiliates, is engaged in the transmission, storage and gathering of natural gas and the transportation and storage of crude oil through interstate pipeline systems. We are a Delaware master limited partnership.

On February 27, 2017, Enbridge Inc. (Enbridge) and Spectra Energy Corp (Spectra Energy) completed a stock-for-stock merger transaction (the Merger) pursuant to which Spectra Energy merged with and into a direct, wholly owned subsidiary of Enbridge, with Spectra Energy continuing as the surviving corporation and a wholly owned subsidiary of Enbridge, and each outstanding share of common stock of Spectra Energy was automatically converted into, and became exchangeable for, 0.984 of Enbridge common share. As a result of the Merger, we became an indirect subsidiary of Enbridge through Enbridge’s ownership of Spectra Energy. As of March 31, 2017, Enbridge and its subsidiaries collectively owned a 75% ownership interest in us (a 73% limited partner interest and a 2% general partner interest), together with 100% of our incentive distribution rights, and the remaining 25% limited partner interest was publicly owned.

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, 2016, 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.

Enbridge and its affiliates are solely responsible for providing the employees and other personnel necessary to conduct our operations. Our costs of doing business have been reflected in our financial accounting records for the periods presented. These costs include direct charges and allocations from Enbridge and its affiliates for business services, such as payroll, accounts payable and facilities management; corporate services, such as finance and accounting, legal, human resources, investor relations, public and regulatory policy, and senior executives; and pension and other post-retirement benefit costs.

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.

XML

Business Segments

3 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Business Segments

Business Segments

We manage our business in two reportable segments: U.S. Transmission and Liquids. The remainder of our business operations is presented as “Other,” and consists of certain corporate costs.

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

The U.S. Transmission segment provides interstate transmission, storage and gathering of natural gas. Substantially all of our operations are subject to the Federal Energy Regulatory Commission (FERC) and the Department of Transportation’s (DOT’s) rules and regulations. Our investments in Gulfstream Natural Gas System, LLC (Gulfstream), Southeast Supply Header, LLC (SESH) and Steckman Ridge, LP are included in U.S. Transmission.

The Liquids segment provides transportation of crude oil. The Express-Platte pipeline system (Express-Platte) is a crude oil pipeline system that connects Canadian and U.S. producers to refineries in the U.S. Rocky Mountain and Midwest regions. These operations are primarily subject to the rules and regulations of the FERC and the National Energy Board (NEB).

Our reportable segments offer different products and services and are managed separately as business units. Management evaluates segment performance based on earnings before interest, taxes, and depreciation and amortization (EBITDA). Cash, cash equivalents and investments are managed centrally, so the gains and losses on foreign currency remeasurement, 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.

Business Segment Data

Condensed Consolidated Statements of Operations	Total Operating Revenues		Depreciation and Amortization		Segment EBITDA/Consolidated Earnings Before Income Taxes
	(in millions)
Three Months Ended March 31, 2017
U.S. Transmission	$	596	$	77	$	479
Liquids	104		8		66
Total reportable segments	700		85		545
Other	—		—		(46		)
Depreciation and amortization	—				85
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	700	$	85	$	359
Three Months Ended March 31, 2016
U.S. Transmission	$	538	$	70	$	411
Liquids	86		7		56
Total reportable segments	624		77		467
Other	—		—		(20		)
Depreciation and amortization	—		—		77
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	624	$	77	$	315

XML

Net Income Per Limited Partner Unit and Cash Distributions

3 Months Ended

Mar. 31, 2017

Equity [Abstract]

Net Income Per Limited Partner Unit and Cash Distributions

Net Income Per Limited Partner Unit and Cash Distributions

The following table presents our net income per limited partner unit calculations:

	Three Months Ended March 31,
	2017		2016
	(in millions, except per unit amounts)
Net income—controlling interests	$	317	$	298
Less:
General partner’s interest in net income attributable to general partner units—2%	6		6
General partner’s interest in net income attributable to incentive distribution rights	83		63
Limited partners’ interest in net income attributable to common units	$	228	$	229
Weighted average limited partner units outstanding—basic and diluted	309		285
Net income per limited partner unit—basic and diluted	$	0.74	$	0.80

Our partnership agreement requires that, within 60 days after the end of each quarter, we distribute all of our Available Cash, as defined, to unitholders of record on the applicable record date.

Available Cash. Available Cash, for any quarter, consists of all cash and cash equivalents on hand at the end of that quarter:

• less the amount of cash reserves established by the general partner to:

• provide for the proper conduct of business,

• comply with applicable law, any debt instrument or other agreement, or

• provide funds for minimum quarterly distributions to the unitholders and to the general partner for any one or more of the next four quarters,

• plus, if the general partner so determines, all or a portion of cash and cash equivalents on hand on the date of determination of Available Cash for the quarter.

Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Common Unit Amount	Common Unitholders		General Partner
Minimum Quarterly Distribution	$0.30	98	%	2	%
First Target Distribution	above $0.30 up to $0.345	98	%	2	%
Second Target Distribution	above $0.345 up to $0.375	85	%	15	%
Third Target Distribution	above $0.375 up to $0.45	75	%	25	%
Thereafter	above $0.45	50	%	50	%

To the extent these incentive distributions are made to the general partner, there will be more Available Cash proportionately allocated to our general partner than to holders of common units. A cash distribution of $0.70125 per limited partner unit was declared on May 4, 2017 and is payable on May 26, 2017 to unitholders of record at the close of business on May 15, 2017.

There is a reduction in the aggregate quarterly distributions, if any, to Spectra Energy, (as indirect holder of incentive distribution rights), by $4 million per quarter for a period of 12 consecutive quarters commencing with the quarter ending on December 31, 2015 through the quarter ending on September 30, 2018. The reduction of distributions is a result of the sale of our interests in DCP Sand Hills Pipeline, LLC (Sand Hills) and DCP Southern Hills Pipeline, LLC (Southern Hills) to Spectra Energy in October 2015.

XML

Variable Interest Entities

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entity Disclosure

Variable Interest Entities

Sabal Trail. In April 2016, NextEra Energy, Inc. (NextEra) purchased a 9.5% interest in Sabal Trail Transmission, LLC (Sabal Trail) from us. See Note 5 for additional information related to this transaction. As of March 31, 2017, we owned a 50% interest in Sabal Trail, a joint venture that is constructing a natural gas pipeline to transport natural gas to Florida. Sabal Trail is a variable interest entity (VIE) due to insufficient equity at risk to finance its activities. We determined that we are the primary beneficiary because we direct the activities of Sabal Trail that most significantly impact its economic performance and we consolidate Sabal Trail in our financial statements. The current estimate of the total remaining construction cost is approximately $0.7 billion.

The following summarizes assets and liabilities for Sabal Trail:

Condensed Consolidated Balance Sheets	March 31, 2017		December 31, 2016
	(in millions)
Assets
Current assets	$	225	$	165
Net property, plant and equipment	2,552		1,942
Regulatory assets and deferred debits	100		79
Total Assets	$	2,877	$	2,186
Liabilities and Equity
Current liabilities	$	285	$	239
Equity	2,592		1,947
Total Liabilities and Equity	$	2,877	$	2,186

Nexus. We own a 50% interest in Nexus Gas Transmission, LLC (Nexus), a joint venture that is constructing a natural gas pipeline from Ohio to Michigan and continuing on to Ontario, Canada. Nexus is a VIE due to insufficient equity at risk to finance its activities. We determined that we are not the primary beneficiary because the power to direct the activities of Nexus that most significantly impact its economic performance is shared. We account for Nexus under the equity method. Our maximum exposure to loss is $1.0 billion. We have an investment in Nexus of $435 million and $356 million as of March 31, 2017 and December 31, 2016, respectively, classified as Investments in and Loans to Unconsolidated Affiliates on our Condensed Consolidated Balance Sheets.

In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of Nexus. See Note 11 for further discussion of the guarantee arrangement.

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Intangible Asset

3 Months Ended

Mar. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Intangible Assets Disclosure

Intangible Asset

During the first quarter of 2016 we entered into a project coordination agreement (PCA) with NextEra, Duke Energy Corporation and Williams Partners L.P. In accordance with the agreement, payments will be made, based on our proportional ownership interest in the Sabal Trail project, as certain milestones of the project are met. During the first quarter of 2016, the first milestone was achieved and paid, consisting of $48 million.

In April 2016, NextEra purchased an additional 9.5% interest in Sabal Trail, reducing our ownership interest in Sabal Trail to 50%. Upon purchase of the additional ownership interest, NextEra reimbursed us $8 million for NextEra’s proportional share of the first milestone payment, which reduced our total milestone payments to $40 million as of June 2016.

During the third quarter of 2016, the second milestone was achieved and paid, consisting of an additional payment of $40 million, for total milestone payments of $80 million as of March 31, 2017 . Both payments are classified as Cash Flows from Investing Activities — Purchase of Intangible, Net. This PCA is an intangible asset and is classified as Investments and Other Assets — Other on our Condensed Consolidated Balance Sheet. The intangible asset will be amortized over a period of 25 years beginning at the time of in-service of Sabal Trail, which is expected to occur during the second quarter of 2017.

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Marketable Securities and Restricted Funds

3 Months Ended

Mar. 31, 2017

Investments, Debt and Equity Securities [Abstract]

Marketable Securities and Restricted Funds

Marketable Securities and Restricted Funds

We routinely invest excess cash and various restricted balances in securities such as commercial paper, corporate debt securities, and other money market securities in the United States, as well as equity securities in 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 the purposes of funding future capital expenditures and NEB regulatory requirements, 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. We had $2 millionand$10 million of AFS securities classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These investments include $2 million and $1 million of restricted funds held and collected from customers for Canadian pipeline abandonment in accordance with the NEB's regulatory requirements, as of March 31, 2017 and December 31, 2016, respectively, as well as $9 million of restricted funds related to certain construction projects as of December 31, 2016.

At March 31, 2017, the weighted-average contractual maturity of outstanding AFS securities was less than one year.

There were no material gross unrecognized holding gains or losses associated with investments in AFS securities at March 31, 2017 or December 31, 2016.

HTM Securities. All of our HTM securities are restricted funds. We had $4 million and $3 million of money market securities classified as Current Assets — Other on the Condensed Consolidated Balance Sheets as of March 31, 2017 and December 31, 2016, respectively. These securities are restricted pursuant to certain Express-Platte debt agreements.

At March 31, 2017, the weighted-average contractual maturity of outstanding HTM securities was less than one year.

There were no material gross unrecognized holding gains or losses associated with investments in HTM securities at March 31, 2017 or December 31, 2016.

Other Restricted Funds. In addition to the AFS and HTM securities that were restricted funds as described above, we had other restricted funds totaling $3 million and $5 million classified as Investments and Other Assets — Other on the Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016, respectively. These restricted funds are related to certain construction projects.

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

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Debt and Credit Facility

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Debt and Credit Facility

Debt and Credit Facility

Available Credit Facility and Restricted Debt Covenants

	Expiration Date	Total Credit Facility Capacity		Commercial Paper Outstanding at March 31, 2017		Available Credit Facility Capacity
		(in millions)
Spectra Energy Partners, LP	2021	$	2,500	$	1,051	$	1,449

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facility. As of March 31, 2017, there were no letters of credit issued or revolving borrowings outstanding under the credit facility.

Our credit agreements contain various covenants, including the maintenance of a consolidated leverage ratio, as defined in the agreements. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of March 31, 2017, 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 our other significant indebtedness or other significant indebtedness of some of our 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.

As noted above, the terms of our credit agreements require us to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the agreement, of 5.0 to 1 or less. As of March 31, 2017, this ratio was 4.1 to 1.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The following presents, for each of the fair value hierarchy levels, assets that are measured at fair value on a recurring basis as of March 31, 2017 and December 31, 2016:

Description	Condensed Consolidated Balance Sheet Caption	March 31, 2017
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	199	$	—	$	199	$	—
Canadian equity securities	Investments and other assets — other	2		2		—		—
Interest rate swaps	Investments and other assets — other	8		—		8		—
Total Assets		$	209	$	2	$	207	$	—

Description	Condensed Consolidated Balance Sheet Caption	December 31, 2016
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	145	$	—	$	145	$	—
Corporate debt securities	Investments and other assets — other	9		—		9		—
Canadian equity securities	Investments and other assets — other	1		1		—		—
Interest rate swaps	Investments and other assets — other	9		—		9		—
Total Assets		$	164	$	1	$	163	$	—

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.

Level 3 Valuation Techniques

Level 3 valuation techniques 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.

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.

	March 31, 2017				December 31, 2016
	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)	6,662		6,826		6,672		6,855

________ 

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

(b) Excludes commercial paper, 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, commercial paper and short-term money market securities 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 three months ended March 31,2017 and 2016, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

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Risk Management and Hedging Activities

3 Months Ended

Mar. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Risk Management and Hedging Activities

Risk Management and Hedging Activities

Changes in interest rates expose us to risk as a result of our issuance of variable and fixed-rate debt and commercial paper. We are exposed to foreign currency risk from the Canadian portion of Express-Platte. 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 exposures. For interest rate derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative as well as the offsetting loss or gain on the hedged item attributable to the hedged risk is recognized in the Condensed Consolidated Statements of Operations. There were no significant amounts of gains or losses recognized in net income during the three months ended March 31, 2017.

At March 31, 2017, we had “pay floating — receive fixed” interest rate swaps outstanding with a total notional amount of $900 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:

	March 31, 2017						December 31, 2016
	Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount		Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount
Description	(in millions)
Assets	$	8	$	—	$	8	$	9	$	—	$	9

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Environmental

We are subject to various federal, state and local laws and regulations 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.

Litigation

Litigation and Legal Proceedings. We are involved in legal, tax and regulatory proceedings in various forums arising in the ordinary course of business, including matters regarding contract and payment claims, some of which involve substantial monetary amounts. We have insurance coverage for certain of these losses should they be incurred. We believe that the final disposition of these proceedings will not have a material effect on our consolidated results of operations, financial position or cash flows.

Legal costs related to the defense of loss contingencies are expensed as incurred. We had no material reserves for legal matters recorded as of March 31, 2017 or December 31, 2016 related to litigation.

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Guarantees

3 Months Ended

Mar. 31, 2017

Guarantees [Abstract]

Guarantees

Guarantees

We have various financial guarantees which are issued in the normal course of business. We enter into these arrangements to facilitate a commercial transaction with a third party by enhancing the value of the transaction to the third party. To varying degrees, these guarantees involve elements of performance and credit risk, which are not included on our Condensed Consolidated Balance Sheets. The possibility of having to perform under these guarantees is largely dependent upon future operations of various subsidiaries, investees and other third parties, or the occurrence of certain future events.

In December 2016, we issued performance guarantees to a third party and an affiliate on behalf of an equity method investee. These guarantees were issued to enable the equity method investee to enter into long-term transportation contracts with the third party. While the likelihood is remote, the maximum potential amount of future payments we could have been required to make as of March 31, 2017 was $61 million. These performance guarantees expire in 2032.

As of March 31, 2017, the amounts recorded for the guarantees described above are not material, both individually and in the aggregate.

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Issuances of Common Units

3 Months Ended

Mar. 31, 2017

Issuances of Common Units [Abstract]

Issuances of Common Units

Issuances of Common Units

During the three months ended March 31, 2017, we issued 0.8 million common units to the public under our at-the-market program, and approximately 17,000 general partner units to our general partner in order for it to maintain a 2% general partner interest. Total net proceeds were $39 million, including approximately $1 million of proceeds from our general partner.

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2017

Accounting Changes and Error Corrections [Abstract]

New Accounting Pronouncements

New Accounting Pronouncements

In October 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control,” to amend the consolidation guidance on how a reporting entity that is the single decision maker of a VIE should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-07, “Investments—Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement to apply the equity method of accounting retrospectively when a reporting entity obtains significant influence over a previously held investment. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments,” which simplifies the embedded derivative analysis for debt instruments containing contingent call or put options. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In March 2016, the FASB issued ASU No. 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships,” which clarifies the hedge accounting impact when there is a change in one of the counterparties to the derivative contract (i.e. novation). We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In July 2015, the FASB issued ASU No. 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory,” which simplifies the subsequent measurement of inventory by requiring inventory to be measured at the lower of cost and net realizable value. We adopted this standard on January 1, 2017 with no material impact on our consolidated results of operations, financial position or cash flows.

In February 2017, the FASB issued ASU No. 2017-05, “Other Income—Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets,”to clarify the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The ASU also clarifies the scope provisions of nonfinancial assets, how to allocate consideration to each distinct asset, and amends the guidance for derecognition of a distinct nonfinancial asset in partial sale transactions. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We are currently evaluating this ASU and its potential impact on us.

In January 2017, the FASB issued ASU No. 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment,” to simplify the subsequent measurement of goodwill. Under the new guidance, goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In January 2017, the FASB issues ASU No. 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” to add guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (disposals) of assets or businesses. We early adopted this standard on January 1, 2017 with no material impact on our consolidated operations, financial position, or cash flows.

In November 2016, the FASB issued ASU No. 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash,” to address the diversity in the classification and presentation of changes in restricted cash and restricted cash equivalents on the statement of cash flows. The update requires that restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In August 2016, the FASB issued ASU No. 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments,” to provide guidance on specific cash flow issues with the objective of reducing the existing diversity in practice. This ASU is effective for us on January 1, 2018. We are currently evaluating this ASU and its potential impact on us.

In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” to provide financial statement users with more useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. Current treatment uses the incurred loss methodology for recognizing credit losses that delays the recognition until it is probable a loss has been incurred. The amendment adds a new impairment model, known as the current expected credit loss model that is based on expected losses rather than incurred losses. Under the new guidance, an entity recognizes as an allowance its estimate of expected credit losses, which the FASB believes will result in more timely recognition of such losses. This ASU is effective for us on January 1, 2020. We are currently evaluating this ASU and its potential impact on us.

In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842),” to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on our consolidated statements of financial position and disclosing additional key information about lease agreements. This ASU is effective for us on January 1, 2019. We are currently evaluating this ASU and its potential impact on us.

In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” to amend the classification and measurement of financial instruments. Changes primarily affect the accounting for equity investments, financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. This ASU is effective for us on January 1, 2018. Early adoption is not permitted. We are currently evaluating this ASU and its potential impact on us.

In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” to significantly enhance consistency and comparability of revenue recognition practices across entities and industries. The new standard establishes a single, principles-based five-step model to be applied to all contracts with customers and introduces new and enhanced disclosure requirements. Since its release, the FASB has issued multiple amendments clarifying and/or amending ASU No. 2014-09. This ASU is effective for us on January 1, 2018 and allows for either full retrospective or modified retrospective adoption. We have substantially completed a review of contracts with customers in relation to the requirements of ASU No. 2014-09. While we have not identified any material difference in the amount or timing of revenue recognition for the categories we have reviewed to date, our evaluation is not complete and we have not concluded on the overall impacts of adopting this standard. In addition, we are in the process of implementing appropriate changes to our business processes, systems and controls to support the recognition and disclosure requirements under the new standard.

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Summary of Operations and Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Use of Estimates, Policy

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.

Derivatives, Offsetting Fair Value Amounts, Policy

For interest rate derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative as well as the offsetting loss or gain on the hedged item attributable to the hedged risk is recognized in the Condensed Consolidated Statements of Operations.

Fair Value Measurement, Policy

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.

Level 3 Valuation Techniques

Level 3 valuation techniques 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.

Sabal Trail

Variable Interest Entity [Line Items]

Consolidation, Variable Interest Entity, Policy

Sabal Trail is a variable interest entity (VIE) due to insufficient equity at risk to finance its activities. We determined that we are the primary beneficiary because we direct the activities of Sabal Trail that most significantly impact its economic performance and we consolidate Sabal Trail in our financial statements.

Nexus

Variable Interest Entity [Line Items]

Consolidation, Variable Interest Entity, Policy

Nexus is a VIE due to insufficient equity at risk to finance its activities. We determined that we are not the primary beneficiary because the power to direct the activities of Nexus that most significantly impact its economic performance is shared. We account for Nexus under the equity method.

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Business Segments (Tables)

3 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Business Segment Data

Business Segment Data

Condensed Consolidated Statements of Operations	Total Operating Revenues		Depreciation and Amortization		Segment EBITDA/Consolidated Earnings Before Income Taxes
	(in millions)
Three Months Ended March 31, 2017
U.S. Transmission	$	596	$	77	$	479
Liquids	104		8		66
Total reportable segments	700		85		545
Other	—		—		(46		)
Depreciation and amortization	—				85
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	700	$	85	$	359
Three Months Ended March 31, 2016
U.S. Transmission	$	538	$	70	$	411
Liquids	86		7		56
Total reportable segments	624		77		467
Other	—		—		(20		)
Depreciation and amortization	—		—		77
Interest expense	—		—		56
Interest income and other	—		—		1
Total consolidated	$	624	$	77	$	315

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Net Income Per Limited Partner Unit and Cash Distributions (Tables)

3 Months Ended

Mar. 31, 2017

Equity [Abstract]

Net Income Per Limited Partner Unit Calculations

The following table presents our net income per limited partner unit calculations:

	Three Months Ended March 31,
	2017		2016
	(in millions, except per unit amounts)
Net income—controlling interests	$	317	$	298
Less:
General partner’s interest in net income attributable to general partner units—2%	6		6
General partner’s interest in net income attributable to incentive distribution rights	83		63
Limited partners’ interest in net income attributable to common units	$	228	$	229
Weighted average limited partner units outstanding—basic and diluted	309		285
Net income per limited partner unit—basic and diluted	$	0.74	$	0.80

Incentive Distribution Rights in Accordance with Partnership Agreement

Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Common Unit Amount	Common Unitholders		General Partner
Minimum Quarterly Distribution	$0.30	98	%	2	%
First Target Distribution	above $0.30 up to $0.345	98	%	2	%
Second Target Distribution	above $0.345 up to $0.375	85	%	15	%
Third Target Distribution	above $0.375 up to $0.45	75	%	25	%
Thereafter	above $0.45	50	%	50	%

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Variable Interest Entities

The following summarizes assets and liabilities for Sabal Trail:

Condensed Consolidated Balance Sheets	March 31, 2017		December 31, 2016
	(in millions)
Assets
Current assets	$	225	$	165
Net property, plant and equipment	2,552		1,942
Regulatory assets and deferred debits	100		79
Total Assets	$	2,877	$	2,186
Liabilities and Equity
Current liabilities	$	285	$	239
Equity	2,592		1,947
Total Liabilities and Equity	$	2,877	$	2,186

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Debt and Credit Facility (Tables)

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Debt and Credit Facility Summary

Available Credit Facility and Restricted Debt Covenants

	Expiration Date	Total Credit Facility Capacity		Commercial Paper Outstanding at March 31, 2017		Available Credit Facility Capacity
		(in millions)
Spectra Energy Partners, LP	2021	$	2,500	$	1,051	$	1,449

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2017

Fair Value Disclosures [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

The following presents, for each of the fair value hierarchy levels, assets that are measured at fair value on a recurring basis as of March 31, 2017 and December 31, 2016:

Description	Condensed Consolidated Balance Sheet Caption	March 31, 2017
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	199	$	—	$	199	$	—
Canadian equity securities	Investments and other assets — other	2		2		—		—
Interest rate swaps	Investments and other assets — other	8		—		8		—
Total Assets		$	209	$	2	$	207	$	—

Description	Condensed Consolidated Balance Sheet Caption	December 31, 2016
		Total		Level 1		Level 2		Level 3
		(in millions)
Corporate debt securities	Cash and cash equivalents	$	145	$	—	$	145	$	—
Corporate debt securities	Investments and other assets — other	9		—		9		—
Canadian equity securities	Investments and other assets — other	1		1		—		—
Interest rate swaps	Investments and other assets — other	9		—		9		—
Total Assets		$	164	$	1	$	163	$	—

Fair Values of Financial Instruments That are Recorded and Carried at Book Value

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.

	March 31, 2017				December 31, 2016
	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)	6,662		6,826		6,672		6,855

________ 

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

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

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Risk Management and Hedging Activities Derivative Assets Offsetting (Tables)

3 Months Ended

Mar. 31, 2017

Offsetting Derivative Assets [Abstract]

Derivative Assets Offsetting Table

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

	March 31, 2017						December 31, 2016
	Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount		Gross Amounts Presented in the Condensed Consolidated Balance Sheet		Amounts Not Offset in the Condensed Consolidated Balance Sheet		Net Amount
Description	(in millions)
Assets	$	8	$	—	$	8	$	9	$	—	$	9

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General (Details)	Mar. 31, 2017
Enbridge Inc.
Business Acquisition
Ownership percentage by parent	75.00%
Publicly Owned
Business Acquisition
Ownership percentage by public	25.00%

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Business Segments (Additional Information) (Details)	3 Months Ended
	Mar. 31, 2017 reportable_segments
Segment Reporting [Abstract]
Number of Reportable Segments	2

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Business Segment Data (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information
Total operating revenues	$ 700	$ 624
Depreciation and amortization	85	77
Interest expense	56	56
Interest income and other	1	1
Earnings from continuing operations before income taxes	359	315
US Transmission
Segment Reporting Information
Total operating revenues	596	538
Earnings before interest taxes depreciation and amortization	479	411
Depreciation and amortization	77	70
Liquids
Segment Reporting Information
Total operating revenues	104	86
Earnings before interest taxes depreciation and amortization	66	56
Depreciation and amortization	8	7
Other
Segment Reporting Information
Earnings before interest taxes depreciation and amortization	(46)	(20)
Total Operating Segments
Segment Reporting Information
Total operating revenues	700	624
Earnings before interest taxes depreciation and amortization	545	467
Depreciation and amortization	$ 85	$ 77

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Net Income Per Limited Partner Unit and Cash Distributions (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Related Party Transaction [Line Items]
Net income—controlling interests	$ 317	$ 298
Less: General partner’s interest in net income	89	69
Limited partners’ interest in net income attributable to common units	$ 228	$ 229
Weighted average limited partner units outstanding—basic and diluted	309	285
Net income per limited partner unit—basic and diluted	$ 0.74	$ 0.80
Partnership Interest
Related Party Transaction [Line Items]
Less: General partner’s interest in net income	$ 6	$ 6
General partner's interest in net income, ownership interest percentage	2.00%	2.00%
Incentive Distribution Rights
Related Party Transaction [Line Items]
Less: General partner’s interest in net income	$ 83	$ 63

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Net Income Per Limited Partner Unit and Cash Distributions - Incentive Distribution Rights in Accordance with Partnership Agreement (Details)	3 Months Ended
	Mar. 31, 2017 $ / shares
Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common Unitholders	98.00%
Marginal Percentage Interest in Distributions General Partner	2.00%
Minimum Quarterly Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.30
First Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common Unitholders	98.00%
Marginal Percentage Interest in Distributions General Partner	2.00%
First Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.345
Second Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common Unitholders	85.00%
Marginal Percentage Interest in Distributions General Partner	15.00%
Second Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.345
Second Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.375
Third Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common Unitholders	75.00%
Marginal Percentage Interest in Distributions General Partner	25.00%
Third Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.375
Third Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.45
Thereafter
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common Unitholders	50.00%
Marginal Percentage Interest in Distributions General Partner	50.00%
Thereafter | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount (in dollars per share)	$ 0.45

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Net Income Per Limited Partner Unit and Cash Distributions (Additional Information) (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
	May 02, 2017	Mar. 31, 2017
Equity [Abstract]
Distribution Made To Member Or Limited Partner Distribution Period		60 days
Subsequent Event
Subsequent Event [Line Items]
Distributions to be paid to unit holders	$ 0.70125
Distribution to limited partner, declaration date	May 04, 2017
Distribution made to limited partner, distribution date	May 26, 2017
Distribution made to limited partner, date of record	May 15, 2017
Incentive Distribution Rights | Subsequent Event
Subsequent Event [Line Items]
Contribution from Parent	$ 4

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Variable Interest Entities (Details) - USD ($) $ in Millions			3 Months Ended
	Apr. 01, 2017	Apr. 01, 2016	Mar. 31, 2017	Dec. 31, 2016
Sabal Trail
Variable Interest Entity [Line Items]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Sale of Interest by Parent		9.50%
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage			50.00%
Variable Interest Entity, Consolidated, Carrying Amount, Assets			$ 2,877	$ 2,186
Variable Interest Entity Consolidated Carrying Amount Liabilities and Equity			2,877	2,186
Sabal Trail | Current Assets
Variable Interest Entity [Line Items]
Variable Interest Entity, Consolidated, Carrying Amount, Assets			225	165
Sabal Trail | Property, Plant and Equipment
Variable Interest Entity [Line Items]
Variable Interest Entity, Consolidated, Carrying Amount, Assets			2,552	1,942
Sabal Trail | Regulatory Assets and Deferred Debits
Variable Interest Entity [Line Items]
Variable Interest Entity, Consolidated, Carrying Amount, Assets			100	79
Sabal Trail | Current Liabilities
Variable Interest Entity [Line Items]
Variable Interest Entity, Consolidated, Carrying Amount, Liabilities			285	239
Sabal Trail | Equity
Variable Interest Entity [Line Items]
Variable Interest Entity Consolidated Carrying Amount Equity			$ 2,592	1,947
Nexus
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage			50.00%
Variable Interest Entity, Reporting Entity Involvement, Maximum Loss Exposure, Amount	$ 1,000
Investments			$ 435	$ 356
Scenario, Forecast | Sabal Trail
Variable Interest Entity [Line Items]
Construction and Development Costs	$ 700

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Intangible Asset (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
	Apr. 01, 2016	Mar. 31, 2017	Sep. 30, 2016	Mar. 31, 2016	Jun. 30, 2016
Finite-Lived Intangible Assets [Line Items]
Purchase of intangible, net		$ 0		$ 48
Sabal Trail
Finite-Lived Intangible Assets [Line Items]
Purchase of intangible, net			$ 40	$ 48	$ 40
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Sale of Interest by Parent	9.50%
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	50.00%
Intangible Assets, Reimbursement of Intangible	$ 8
Finite-Lived Intangible Assets, Gross		$ 80
Finite-Lived Intangible Asset, Useful Life		25 years

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Marketable Securities and Restricted Funds - Schedule of Available-for-Sale Securities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale Securities, Accumulated Gross Unrealized Gain (Loss), before Tax	$ 0	$ 0
Investments and Other Assets - Other
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale Securities	2	10
Canadian Pipeline Abandonment Requirement | Investments and Other Assets - Other
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale Securities	$ 2	1
Project Costs | Investments and Other Assets - Other
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale Securities		$ 9
Available-for-sale Securities | Maximum
Schedule of Available-for-sale Securities [Line Items]
Available-for-sale securities, contractual maturity	1 year

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Marketable Securities and Restricted Funds - Schedule of Held-to-Maturity Securities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Schedule of Held-to-maturity Securities [Line Items]
Held-to-maturity Securities, Accumulated Unrecognized Holding Gain	$ 0	$ 0
Held-to-maturity Securities, Accumulated Unrecognized Holding Loss	0	0
Current Assets - Other | Money Market Funds
Schedule of Held-to-maturity Securities [Line Items]
Held-to-maturity Securities, Fair Value	$ 4	$ 3
Held-to-maturity Securities | Maximum
Schedule of Held-to-maturity Securities [Line Items]
Held-to-maturity securities, contractual maturity	1 year

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Marketable Securities and Restricted Funds Marketable Securities and Restricted Funds - Other Restricted Funds (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Project Costs | Investments and Other Assets - Other
Gain (Loss) on Investments [Line Items]
Restricted Cash and Cash Equivalents, Noncurrent	$ 3	$ 5

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Debt and Credit Facility (Additional Information) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)
Line of Credit Facility [Line Items]
Expiration Date	2021
Total Credit Facility Capacity	$ 2,500
Commercial Paper Outstanding at March 31, 2017	1,051	$ 574
Available Credit Facility Capacity	$ 1,449
Debt To EBITDA Ratio	4.1
Maximum
Line of Credit Facility [Line Items]
Debt To EBITDA Ratio	5.0

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Fair Value Measurements - Fair Value Hierarchy Levels, Assets that are Measured at Fair Value on a Recurring Basis (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	$ 209	$ 164
Fair Value, Inputs, Level 1
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	2	1
Fair Value, Inputs, Level 2
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	207	163
Corporate Debt Securities | Cash and Cash Equivalents
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	199	145
Corporate Debt Securities | Cash and Cash Equivalents | Fair Value, Inputs, Level 2
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	199	145
Corporate Debt Securities | Investments and Other Assets - Other
Financial Instruments [Line Items]
Assets, Fair Value Disclosure		9
Corporate Debt Securities | Investments and Other Assets - Other | Fair Value, Inputs, Level 2
Financial Instruments [Line Items]
Assets, Fair Value Disclosure		9
Interest Rate Swap | Investments and Other Assets - Other
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	8	9
Interest Rate Swap | Investments and Other Assets - Other | Fair Value, Inputs, Level 2
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	8	9
CANADA | Canadian Equity Securities | Investments and Other Assets - Other
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	2	1
CANADA | Canadian Equity Securities | Investments and Other Assets - Other | Fair Value, Inputs, Level 1
Financial Instruments [Line Items]
Assets, Fair Value Disclosure	$ 2	$ 1

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Fair Value Measurements - Fair Values of Financial Instruments Recorded and Carried at Book Value (Details) - USD ($) $ in Millions		Mar. 31, 2017	Dec. 31, 2016
Book Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Note receivable, noncurrent	[1]	$ 71	$ 71
Long-term debt, including current maturities	[2]	6,662	6,672
Approximate Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions
Note receivable, noncurrent	[1]	71	71
Long-term debt, including current maturities	[2]	$ 6,826	$ 6,855

[1] Included within Investments in and Loans to Unconsolidated Affiliates.

[2] Excludes commercial paper, unamortized items and fair value hedge carrying value adjustments.

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Risk Management and Hedging Activities (Details) - Interest Rate Swap - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Derivative [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	$ 0
Derivative Asset, Fair Value, Gross Asset	8	$ 9
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	0
Derivative Asset	$ 8	$ 9

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Risk Management and Hedging Activities - Additional Detail (Details) $ in Millions	Mar. 31, 2017 USD ($)
Interest Rate Swap
Derivative [Line Items]
Derivative, Notional Amount	$ 900

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Guarantees (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($)
Guarantees [Abstract]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 61
Guarantor Obligations, Term	2032

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Issuances of Common Units (Additional Information) (Detail) - USD ($) shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Issuances of Common Units [Line Items]
Proceeds from issuance of common units	$ 39	$ 82
Limited Partners Common
Issuances of Common Units [Line Items]
Partners units issued (in shares)	800
General Partner
Issuances of Common Units [Line Items]
Partners units issued (in shares)	17
Proceeds from issuance of common units	$ 1
Limited Partner and General Partner
Issuances of Common Units [Line Items]
Proceeds from issuance of common units	$ 39