Spectra Energy 10-K 27 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Jan. 31, 2015	Jun. 30, 2014
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	SE
Entity Registrant Name	SPECTRA ENERGY CORP.
Entity Central Index Key	1373835
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		671,089,528
Entity Public Float			$28,000,000,000

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Operating Revenues
Transportation, storage and processing of natural gas	$3,291		$3,128		$3,149
Distribution of natural gas	1,583		1,577		1,366
Sales of natural gas liquids	497		440		401
Transportation of crude oil	302		224		0
Other	230		149		159
Total operating revenues	5,903	[1]	5,518	[1]	5,075	[1]
Operating Expenses
Natural gas and petroleum products purchased	1,219		1,139		1,037
Operating, maintenance and other	1,571		1,568		1,380
Depreciation and amortization	796	[1]	772	[1]	746	[1]
Property and other taxes	393		373		337
Total operating expenses	3,979		3,852		3,500
Operating Income	1,924		1,666		1,575
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	361		445		382
Other income and expenses, net	59		124		83
Total other income and expenses	420		569		465
Interest Expense	679		657		625
Earnings From Continuing Operations Before Income Taxes	1,665	[1]	1,578	[1]	1,415	[1]
Income Tax Expense From Continuing Operations	382		419		370
Income From Continuing Operations	1,283		1,159		1,045
Income From Discontinued Operations, net of tax	0		0		2
Net Income	1,283		1,159		1,047
Net Income — Noncontrolling Interests	201		121		107
Net Income — Controlling Interests	$1,082		$1,038		$940
Weighted-average shares outstanding
Basic (in shares)	671		669		653
Diluted (in shares)	672		671		656
Earnings per share
Basic (in usd per share)	$1.61	[2]	$1.55	[2]	$1.44
Diluted (in usd per share)	$1.61	[2]	$1.55	[2]	$1.43
Dividends per share (in usd per share)	$1.38		$1.22		$1.15
[1]	Excludes amounts associated with entities included in discontinued operations.
[2]	Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to rounding.

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net Income	$1,283	$1,159	$1,047
Other comprehensive income (loss):
Foreign currency translation adjustments	-548	-494	215
Non-cash mark-to-market net gain on hedges	4	7	6
Reclassification of cash flow hedges into earnings	5	7	9
Pension and benefits impact (net of tax benefit (expense) of $14, $(88) and $6, respectively)	-47	203	9
Other	0	2	0
Total other comprehensive income (loss)	-586	-275	239
Total Comprehensive Income, net of tax	697	884	1,286
Less: Comprehensive Income — Noncontrolling Interests	194	114	110
Comprehensive Income — Controlling Interests	$503	$770	$1,176

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Comprehensive Income [Abstract]
Tax benefit (expense) on pension and benefits impact	$14	($88)	$6

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets
Cash and cash equivalents	$215		$201
Receivables (net of allowance for doubtful accounts of $11 and $10 at December 31, 2014 and 2013, respectively)	1,336		1,336
Inventory	313		263
Fuel tracker	102		28
Other	366		253
Total current assets	2,332		2,081
Investments and Other Assets
Investments in and loans to unconsolidated affiliates	2,966		3,043
Goodwill	4,714		4,810
Other	327		385
Total investments and other assets	8,007		8,238
Property, Plant and Equipment
Cost	29,211		28,456
Less accumulated depreciation and amortization	6,904		6,627
Net property, plant and equipment	22,307		21,829
Regulatory Assets and Deferred Debits	1,394		1,385
Total Assets	34,040		33,533
Current Liabilities
Accounts payable	458		440
Commercial paper	1,583	[1],[2]	1,032	[1],[2]
Taxes accrued	91		72
Interest accrued	181		201
Current maturities of long-term debt	327		1,197
Other	1,169		1,097
Total current liabilities	3,809		4,039
Long-term Debt	12,769		12,488
Deferred Credits and Other Liabilities
Deferred income taxes	5,405		4,968
Regulatory and other	1,401		1,457
Total deferred credits and other liabilities	6,806		6,425
Commitments and Contingencies
Preferred Stock of Subsidiaries	258		258
Equity
Preferred stock, $0.001 par, 22 million shares authorized, no shares outstanding	0		0
Common stock, $0.001 par, 1 billion shares authorized, 671 million and 670 million shares outstanding at December 31, 2014 and 2013, respectively	1		1
Additional paid-in capital	4,956		4,869
Retained earnings	2,541		2,383
Accumulated other comprehensive income	662		1,241
Total controlling interests	8,160		8,494
Noncontrolling interests	2,238		1,829
Total equity	10,398		10,323
Total Liabilities and Equity	$34,040		$33,533
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Receivables, allowance for doubtful accounts	$11	$10
Preferred stock, par value (in usd per share)	$0.00	$0.00
Preferred stock, shares authorized	22,000,000	22,000,000
Preferred stock, shares outstanding	0	0
Common stock, par value (in usd per share)	$0.00	$0.00
Common stock, shares authorized	1,000,000,000	1,000,000,000
Common stock, shares outstanding	671,000,000	670,000,000

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$1,283	$1,159	$1,047
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	809	787	760
Deferred income tax expense	388	421	210
Equity in earnings of unconsolidated affiliates	-361	-445	-382
Distributions received from unconsolidated affiliates	380	324	307
Decrease (increase) in
Receivables	-9	-94	69
Inventory	-106	17	80
Other current assets	-143	-88	1
Increase (decrease) in
Accounts payable	25	-2	-51
Taxes accrued	28	-8	14
Other current liabilities	3	101	43
Other, assets	-33	-111	-74
Other, liabilities	-43	-31	-86
Net cash provided by operating activities	2,221	2,030	1,938
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	-2,028	-1,947	-2,025
Investments in and loans to unconsolidated affiliates	-259	-312	-520
Acquisitions, net of cash acquired	0	-1,254	-30
Purchases of held-to-maturity securities	-790	-985	-2,671
Proceeds from sales and maturities of held-to-maturity securities	815	1,023	2,578
Purchases of available-for-sale securities	-13	-5,878	-644
Proceeds from sales and maturities of available-for-sale securities	7	6,024	514
Distributions received from unconsolidated affiliates	266	87	17
Loan to unconsolidated affiliate	0	-71	0
Repayment of loan to unconsolidated affiliate	0	71	0
Other changes in restricted funds	-1	2	93
Other	0	4	14
Net cash used in investing activities	-2,003	-3,236	-2,674
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,028	4,372	1,301
Payments for the redemption of long-term debt	-1,184	-2,139	-525
Net increase (decrease) in commercial paper	574	-206	199
Distributions to noncontrolling interests	-175	-144	-120
Contributions from noncontrolling interests	145	23	0
Proceeds from the issuance of Spectra Energy common stock	0	0	382
Proceeds from the issuance of Spectra Energy Partners, LP common units	327	214	145
Dividends paid on common stock	-925	-821	-753
Other	11	17	25
Net cash provided by (used in) financing activities	-199	1,316	654
Effect of exchange rate changes on cash	-5	-3	2
Net increase (decrease) in cash and cash equivalents	14	107	-80
Cash and cash equivalents at beginning of period	201	94	174
Cash and cash equivalents at end of period	215	201	94
Supplemental Disclosures
Cash paid for interest, net of amount capitalized	684	625	601
Net cash paid (refunds received) for income taxes	-8	43	130
Property, plant and equipment non-cash accruals	$125	$112	$147

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (USD $)	Total	Common Stock	Additional Paid-in Capital	Retained Earnings	Foreign Currency Translation Adjustments	Other	Noncontrolling Interests
In Millions, unless otherwise specified
Beginning Balance at Dec. 31, 2011	$8,896	$1	$4,814	$1,977	$1,832	($559)	$831
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,047			940			107
Other comprehensive income	239				212	24	3
Dividends on common stock	-752			-752
Stock-based compensation	24		24
Distributions to noncontrolling interests	-120						-120
Contributions from noncontrolling interest	0
Spectra Energy common stock issued	399		399
Spectra Energy Partners, LP common units issued	134		26				108
Transfer of interests in subsidiaries to Spectra Energy Partners, LP	-20		34				-54
Other, net	-4						-4
Ending Balance at Dec. 31, 2012	9,843	1	5,297	2,165	2,044	-535	871
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,159			1,038			121
Other comprehensive income	-275				-487	219	-7
Dividends on common stock	-820			-820
Stock-based compensation	19		19
Distributions to noncontrolling interests	-144						-144
Contributions from noncontrolling interest	23						23
Spectra Energy common stock issued	23		23
Spectra Energy Partners, LP common units issued	189		42				147
Transfer of interests in subsidiaries to Spectra Energy Partners, LP	306		-511				817
Other, net	0		-1				1
Ending Balance at Dec. 31, 2013	10,323	1	4,869	2,383	1,557	-316	1,829
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,283			1,082			201
Other comprehensive income	-586				-541	-38	-7
Dividends on common stock	-924			-924
Stock-based compensation	19		19
Distributions to noncontrolling interests	-175						-175
Contributions from noncontrolling interest	145						145
Spectra Energy common stock issued	11		11
Spectra Energy Partners, LP common units issued	297		49				248
Transfer of interests in subsidiaries to Spectra Energy Partners, LP	2		3				-1
Other, net	3		5				-2
Ending Balance at Dec. 31, 2014	$10,398	$1	$4,956	$2,541	$1,016	($354)	$2,238

Summary_of_Operations_and_Sign

Summary of Operations and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Operations and Significant Accounting Policies	Summary of Operations and Significant Accounting Policies
	The terms “we,” “our,” “us” and “Spectra Energy” as used in this report refer collectively to Spectra Energy Corp and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity within Spectra Energy. The term “Spectra Energy Partners” refers to our Spectra Energy Partners operating segment. The term “SEP” refers to Spectra Energy Partners, LP, our master limited partnership.
	Nature of Operations. Spectra Energy Corp, through its subsidiaries and equity affiliates, owns and operates a large and diversified portfolio of complementary natural gas-related energy assets, and owns and operates a crude oil pipeline system that connects Canadian and U.S. producers to refineries in the U.S. Rocky Mountain and Midwest regions. We currently operate in three key areas of the natural gas industry: gathering and processing, transmission and storage, and distribution. We provide transmission and storage of natural gas to customers in various regions of the northeastern and southeastern United States, the Maritime Provinces in Canada, the Pacific Northwest in the United States and Canada, and in the province of Ontario, Canada. We also provide natural gas sales and distribution services to retail customers in Ontario, and natural gas gathering and processing services to customers in western Canada. We also own a 50% interest in DCP Midstream, LLC (DCP Midstream), based in Denver, Colorado, one of the leading natural gas gatherers in the United States based on wellhead volumes, and one of the largest U.S. producers and marketers of natural gas liquids (NGLs).
	Basis of Presentation. The accompanying Consolidated Financial Statements include our accounts and the accounts of our majority-owned subsidiaries, after eliminating intercompany transactions and balances.
	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 Consolidated Financial Statements and Notes to Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.
	Fair Value Measurements. We measure the fair value of financial assets and liabilities by maximizing the use of observable inputs and minimizing the use of unobservable inputs. Fair value is the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.
	Cost-Based Regulation. The economic effects of regulation can result in a regulated company recording assets for costs that have been or are expected to be approved for recovery from customers or recording liabilities for amounts that are expected to be returned to customers or for instances where the regulator provides current rates that are intended to recover costs that are expected to be incurred in the future. Accordingly, we record assets and liabilities that result from the regulated ratemaking process that may not be recorded under GAAP for non-regulated entities. We continually assess whether regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes and recent rate orders to other regulated entities. Based on this assessment, we believe our existing regulatory assets are probable of recovery. These regulatory assets and liabilities are mostly classified in the Consolidated Balance Sheets as Regulatory Assets and Deferred Debits, and Deferred Credits and Other Liabilities — Regulatory and Other. We evaluate our regulated assets, and consider factors such as regulatory changes and the effect of competition. If cost-based regulation ends or competition increases, we may have to reduce our asset balances to reflect a market basis less than cost and write-off the associated regulatory assets and liabilities. See Note 5 for further discussion.
	Foreign Currency Translation. The Canadian dollar has been determined to be the functional currency of our Canadian operations based on an assessment of the economic circumstances of those operations. Assets and liabilities of our Canadian operations are translated into U.S. dollars at current exchange rates. Translation adjustments resulting from fluctuations in exchange rates are included as a separate component of Other Comprehensive Income on the Consolidated Statements of Comprehensive Income. Revenue and expense accounts of these operations are translated at average monthly exchange rates prevailing during the periods. Gains and losses arising from transactions denominated in currencies other than the functional currency are included in the results of operations of the period in which they occur. Foreign currency transaction gains (losses) totaled $3 million in 2014, $1 million in 2013 and $(3) million in 2012, and are included in Other Income and Expenses, Net on the Consolidated Statements of Operations. Deferred U.S. taxes related to translation gains and losses have not been provided on those Canadian operations that we expect the earnings to be indefinitely reinvested.
	Revenue Recognition. Revenues from the transmission, storage, processing, distribution and sales of natural gas, from the sales of NGLs and from the transportation and storage of crude oil are generally recognized when either the service is provided or the product is delivered. Revenues related to these services provided or products delivered but not yet billed are estimated each month. These estimates are generally based on contract data, regulatory information, estimated distribution usage based on historical data adjusted for heating degree days, commodity prices and preliminary throughput and allocation measurements. Final bills for the current month are billed and collected in the following month. Differences between actual and estimated unbilled revenues are immaterial. There were no customers accounting for 10% or more of consolidated revenues during 2014, 2013 or 2012. We also have certain customer contracts with billed amounts that decline annually over the terms of the contracts. Differences between the amounts billed and recognized are deferred on the Consolidated Balance Sheets.
	Stock-Based Compensation. For employee awards, equity-classified and liability-classified stock-based compensation cost is measured at the grant date based on the fair value of the award. Liability-classified stock-based compensation cost is remeasured at each reporting period until settlement. Related compensation expense is recognized over the requisite service period, which generally begins on the date the award is granted through the earlier of the date the award vests, the date the employee becomes retirement-eligible or the date the market or performance condition of the award is met. Awards, including stock options, granted to employees that are retirement-eligible are deemed to have vested immediately upon issuance, and therefore, compensation cost for those awards is recognized on the date such awards are granted. See Note 24 for further discussion.
	Pension and Other Post-Retirement Benefits. We fully recognize the overfunded or underfunded status of our consolidating subsidiaries’ pension and other post-retirement benefit plans as Investments and Other Assets - Other, Current Liabilities - Other or Deferred Credits and Other Liabilities - Regulatory and Other in the Consolidated Balance Sheets, as appropriate. A plan’s funded status is the difference between the fair value of plan assets and the plan’s projected benefit obligation. We record deferred plan costs and income (unrecognized losses and gains, and unrecognized prior service costs and credits) in Accumulated Other Comprehensive Income (AOCI) on the Consolidated Statements of Equity, until they are amortized and recognized as a component of benefit expense within Operating, Maintenance and Other in the Consolidated Statements of Operations. See Note 25 for further discussion.
	Allowance for Funds Used During Construction (AFUDC). AFUDC, which represents the estimated debt and equity costs of capital funds necessary to finance the construction of certain new regulated facilities, consists of two components, an equity component and an interest expense component. The equity component is a non-cash item. After construction is completed, we are permitted to recover these costs through inclusion in the rate base and in the depreciation provision. AFUDC is capitalized as a component of Property, Plant and Equipment - Cost in the Consolidated Balance Sheets, with offsetting credits to the Consolidated Statements of Operations through Other Income and Expenses, Net for the equity component and Interest Expense for the interest expense component. The total amount of AFUDC included in the Consolidated Statements of Operations was $72 million in 2014 (an equity component of $53 million and an interest expense component of $19 million), $155 million in 2013 (an equity component of $105 million and an interest expense component of $50 million) and $131 million in 2012 (an equity component of $85 million and an interest expense component of $46 million).
	Income Taxes. Deferred income taxes are recognized for differences between the financial reporting and tax bases of assets and liabilities at enacted statutory tax rates in effect for the years in which the differences are expected to reverse. The effect on deferred taxes of a change in tax rates is recognized in income in the period that includes the enactment date. Actual income taxes could vary from these estimates due to future changes in income tax law or results from the final review of tax returns by federal, state or foreign tax authorities.
	Financial statement effects on tax positions are recognized in the period in which it is more likely than not that the position will be sustained upon examination, the position is effectively settled or when the statute of limitations to challenge the position has expired. Interest and penalties related to unrecognized tax benefits are recorded as interest expense and other expense, respectively.
	Cash and Cash Equivalents. Highly liquid investments with original maturities of three months or less at the date of acquisition, except for the investments that were pledged as collateral against long-term debt as discussed in Note 16 and any investments that are considered restricted funds, are considered cash equivalents.
	Inventory. Inventory consists of natural gas and NGLs held in storage for transmission and processing, and also includes materials and supplies. Natural gas inventories primarily relate to the Distribution segment in Canada and are valued at costs approved by the regulator, the Ontario Energy Board (OEB). The difference between the approved price and the actual cost of gas purchased is recorded in either accounts receivable or other current liabilities, as appropriate, for future disposition with customers, subject to approval by the OEB. The remaining inventory is recorded at the lower of cost or market, primarily using average cost.
	Natural Gas Imbalances. The Consolidated Balance Sheets include in-kind balances as a result of differences in gas volumes received and delivered for customers. Since settlement of certain imbalances is in-kind, changes in their balances do not have an effect on our Consolidated Statements of Cash Flows. Receivables include $642 million and $606 million as of December 31, 2014 and December 31, 2013, respectively, and Other Current Liabilities include $634 million and $575 million as of December 31, 2014 and December 31, 2013, respectively, related to gas imbalances. Most natural gas volumes owed to or by us are valued at natural gas market index prices as of the balance sheet dates.
	Risk Management and Hedging Activities and Financial Instruments. Currently, our use of derivative instruments is primarily limited to interest rate positions and commodity pricing. All derivative instruments that do not qualify for the normal purchases and normal sales exception are recorded on the Consolidated Balance Sheets at fair value. Cash inflows and outflows related to derivative instruments are a component of Cash Flows From Operating Activities in the accompanying Consolidated Statements of Cash Flows.
	Cash Flow and Fair Value Hedges. Qualifying energy commodity and other derivatives may be designated as either a hedge of a forecasted transaction (cash flow hedge) or a hedge of a recognized asset, liability or firm commitment (fair value hedge). For all hedge contracts, we prepare documentation of the hedge in accordance with accounting standards and assess whether the hedge contract is highly effective using regression analysis, both at inception and on a quarterly basis, in offsetting changes in cash flows or fair values of hedged items. We document hedging activity by instrument type (futures or swaps) and risk management strategy (commodity price risk or interest rate risk).
	For derivatives designated as fair value hedges, we recognize the gain or loss on the derivative instrument, as well as the offsetting gain or loss on the hedged item in earnings, to the extent effective, in the current period. In the event the hedge is not effective, there is no offsetting gain or loss recognized in earnings for the hedged item. All derivatives designated and accounted for as hedges are classified in the same category as the item being hedged in the Consolidated Statements of Cash Flows. All components of each derivative gain or loss are included in the assessment of hedge effectiveness.
	Investments. We may actively invest a portion of our available cash and restricted funds balances in various financial instruments, including taxable or tax-exempt debt securities. In addition, we invest in short-term money market securities, some of which are restricted due to debt collateral or insurance requirements. Investments in available-for-sale (AFS) securities are carried at fair value and investments in held-to-maturity (HTM) securities are carried at cost. Investments in money market securities are also accounted for at fair value. Realized gains and losses, and dividend and interest income related to these securities, including any amortization of discounts or premiums arising at acquisition, are included in earnings. The costs of securities sold are determined using the specific identification method. Purchases and sales of AFS and HTM securities are presented on a gross basis within Cash Flows From Investing Activities in the accompanying Consolidated Statements of Cash Flows.
	Goodwill. We perform our goodwill impairment test annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. No impairments of goodwill were recorded in 2014, 2013 or 2012. See Note 12 for further discussion.
	We perform our annual review for goodwill impairment at the reporting unit level, which is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. We determined that our reporting units are equivalent to our reportable segments, except for the reporting units of our Western Canada Transmission & Processing and Spectra Energy Partners reportable segments, which are one level below.
	As permitted under accounting guidance on testing goodwill for impairment, we perform either a qualitative assessment or a quantitative assessment of each of our reporting units based on management’s judgment. With respect to our qualitative assessments, we consider events and circumstances specific to us, such as macroeconomic conditions, industry and market considerations, cost factors and overall financial performance, when evaluating whether it is more likely than not that the fair values of our reporting units are less than their respective carrying amounts.
	In connection with our quantitative assessments, we primarily use a discounted cash flow analysis to determine the fair
	values of those reporting units. Key assumptions in the determination of fair value included the use of an appropriate discount
	rate and estimated future cash flows. In estimating cash flows, we incorporate expected long-term growth rates in key markets
	served by our operations, regulatory stability, the ability to renew contracts, commodity prices (where appropriate) and foreign
	currency exchange rates, as well as other factors that affect our reporting units’ revenue, expense and capital expenditure
	projections. If the carrying amount of the reporting unit exceeds its fair value, a comparison of the fair value and carrying value
	of the goodwill of that reporting unit needs to be performed. If the carrying value of the goodwill of a reporting unit exceeds
	the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to the excess. Additional
	impairment tests are performed between the annual reviews if events or changes in circumstances make it more likely than not
	that the fair value of a reporting unit is below its carrying amount.
	Property, Plant and Equipment. Property, plant and equipment is stated at historical cost less accumulated depreciation. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect costs include general engineering, taxes and the cost of funds used during construction. The costs of renewals and betterments that extend the useful life or increase the expected output of property, plant and equipment are also capitalized. The costs of repairs, replacements and major maintenance projects that do not extend the useful life or increase the expected output of property, plant and equipment are expensed as incurred. Depreciation is generally computed over the asset’s estimated useful life using the straight-line method.
	When we retire regulated property, plant and equipment, we charge the original cost plus the cost of retirement, less salvage value, to accumulated depreciation and amortization. When we sell entire regulated operating units or retire non-regulated properties, the cost is removed from the property account and the related accumulated depreciation and amortization accounts are reduced. Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body.
	Preliminary Project Costs. Project development costs, including expenditures for preliminary surveys, plans, investigations, environmental studies, regulatory applications and other costs incurred for the purpose of determining the feasibility of capital expansion projects, are capitalized for rate-regulated enterprises when it is determined that recovery of such costs through regulated revenues of the completed project is probable. Any inception-to-date costs of the project that were initially expensed are reversed and capitalized as Property, Plant and Equipment.
	Long-Lived Asset Impairments. We evaluate whether long-lived assets, excluding goodwill, have been impaired when circumstances indicate the carrying value of those assets may not be recoverable. For such long-lived assets, an impairment exists when its carrying value exceeds the sum of estimates of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, a probability-weighted approach is used in developing estimates of future undiscounted cash flows. If the carrying value of the long-lived asset is not recoverable based on these estimated future undiscounted cash flows, an impairment loss is measured as the excess of the asset’s carrying value over its fair value, such that the asset’s carrying value is adjusted to its estimated fair value.
	We assess the fair value of long-lived assets using commonly accepted techniques and may use more than one source. Sources to determine fair value include, but are not limited to, recent third-party comparable sales, internally developed discounted cash flow analyses and analyses from outside advisors. Significant changes in market conditions resulting from events such as changes in natural gas available to our systems, the condition of an asset, a change in our intent to utilize the asset or a significant change in contracted revenues or regulatory recoveries would generally require us to reassess the cash flows related to the long-lived assets.
	Asset Retirement Obligations. We recognize asset retirement obligations (AROs) for legal commitments associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made and is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset.
	Unamortized Debt Premium, Discount and Expense. Premiums, discounts and expenses incurred with the issuance of outstanding long-term debt are amortized over the terms of the debt issues. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations to finance regulated assets and operations are amortized consistent with regulatory treatment of those items, where appropriate.
	Environmental Expenditures. We expense environmental expenditures related to conditions caused by past operations that do not generate current or future revenues. Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Undiscounted liabilities are recorded when the necessity for environmental remediation becomes probable and the costs can be reasonably estimated, or when other potential environmental liabilities are reasonably estimable and probable.
	Captive Insurance Reserves. We have captive insurance subsidiaries which provide insurance coverage to our consolidated subsidiaries as well as certain equity affiliates, on a limited basis, for various business risks and losses, such as workers compensation, property, business interruption and general liability. Liabilities include provisions for estimated losses incurred but not yet reported, as well as provisions for known claims which have been estimated on a claims-incurred basis. Incurred but not yet reported reserve estimates involve the use of assumptions and are based upon historical loss experience, industry data and other actuarial assumptions. Reserve estimates are adjusted in future periods as actual losses differ from historical experience.
	Guarantees. Upon issuance or material modification of a guarantee made by us, we recognize a liability for the estimated fair value of the obligation we assume under that guarantee, if any. Fair value is estimated using a probability-weighted approach. We reduce the obligation over the term of the guarantee or related contract in a systematic and rational method as risk is reduced under the obligation.
	Accounting For Sales of Stock by a Subsidiary. Sales of stock by a consolidated subsidiary are accounted for as equity transactions in those instances where a change in control does not take place.
	Segment Reporting. Operating segments are components of an enterprise for which separate financial information is available and evaluated regularly by the chief operating decision maker in deciding how to allocate resources and evaluate performance. Two or more operating segments may be aggregated into a single reportable segment provided certain criteria are met. There is no such aggregation within our defined business segments. A description of our reportable segments, consistent with how business results are reported internally to management, and the disclosure of segment information is presented in Note 4.
	Consolidated Statements of Cash Flows. Cash flows from discontinued operations are combined with cash flows from continuing operations within operating, investing and financing cash flows. Cash received from insurance proceeds are classified depending on the activity that resulted in the insurance proceeds. For example, business interruption insurance proceeds are included as a component of operating activities while insurance proceeds from damaged property are included as a component of investing activities. With respect to cash overdrafts, book overdrafts are included within operating cash flows while bank overdrafts, if any, are included within financing cash flows. Cash flows from borrowings and repayments under revolving credit facilities that had documented original maturities of 90 days or less are reported on a net basis as Net Increase (Decrease) in Revolving Credit Facilities Borrowings within financing activities.
	Distributions from Unconsolidated Affiliates. We consider distributions received from unconsolidated affiliates which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and classify these amounts as Cash Flows From Operating Activities within the accompanying Consolidated Statements of Cash Flows. Cumulative distributions received in excess of cumulative equity in earnings subsequent to the date of investment are considered to be a return of investment and are classified as Cash Flows From Investing Activities.
	New Accounting Pronouncements. The following new Accounting Standards Update (ASU) was adopted during 2014 and the effect of such adoption has been presented in the accompanying Consolidated Financial Statements:
	ASU No. 2013-11. In July 2013, the Financial Accounting Standards Board (FASB) issued ASU No. 2013-11, “Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (a Consensus of the FASB Emerging Issues Task Force),” which was issued to eliminate diversity in practice. This ASU requires entities to net unrecognized tax benefits against all same-jurisdiction net operating losses or tax credit carryforwards that would be used to settle the position with a tax authority. We adopted this standard on January 1, 2014. The adoption of this ASU did not have a material impact on our consolidated results of operations, financial position or cash flows.
	Pending. The following new accounting pronouncements were issued but not adopted as of December 31, 2014:
	ASU No. 2014-08. In April 2014, the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” This ASU revises the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have or will have a major effect on an entity’s operations and financial results, removing the lack of continuing involvement criteria and requiring discontinued operations reporting for the disposal of an equity method investment that meets the definition of discontinued operations. The update also requires expanded disclosures for discontinued operations, and disclosure of pretax profit or loss of certain individually significant components of an entity that do not qualify for discontinued operations reporting. This ASU was effective for us on January 1, 2015 and had no impact on our consolidated results of operations, financial position or cash flows.
	ASU No. 2014-09. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606)” which supersedes the revenue recognition requirements of “Revenue Recognition (Topic 605)” and clarifies the principles of recognizing revenue. This ASU is effective for us January 1, 2017. We are currently evaluating this ASU and its potential impact on us.
	2013. There were no significant accounting pronouncements issued during 2013 that had a material impact on our consolidated results of operations, financial position or cash flows.
	2012. There were no significant accounting pronouncements issued during 2012 that had a material impact on our consolidated results of operations, financial position or cash flows.

Spectra_Energy_Partners_LP

Spectra Energy Partners, LP	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Spectra Energy Partners, LP	Spectra Energy Partners, LP
	SEP is our natural gas infrastructure and crude oil pipeline master limited partnership. As of December 31, 2014, Spectra Energy owned 82% of SEP, including a 2% general partner interest.
	U.S. Assets Dropdown. In August 2013, Spectra Energy entered into a contribution agreement with SEP (the Contribution Agreement), pursuant to which Spectra Energy agreed to contribute to SEP substantially all of Spectra Energy’s interests in its subsidiaries that own U.S. transmission and storage and liquids assets, including its remaining 60% interest in the U.S. portion of Express-Platte, and to assign to SEP its interests in certain related contracts (collectively, the U.S. Assets Dropdown).
	In November 2013, Spectra Energy completed the closing of substantially all of the U.S. Assets Dropdown. This first of three planned transactions consisted of all the contributed entities contemplated in the Contribution Agreement, excluding a 25.05% ownership interest in Southeast Supply Header, LLC (SESH) and a 1% ownership interest in Steckman Ridge, LP (Steckman Ridge). Consideration to Spectra Energy for the November 2013 closing included $2.3 billion in cash, assumption by SEP (indirectly by acquisition of the contributed entities) of approximately $2.4 billion of third-party indebtedness of the contributed entities, 167.6 million newly issued SEP limited partner units and 3.4 million newly issued general partner units. This transfer of assets between entities under common control resulted in a decrease to Additional Paid-in Capital of $733 million ($458 million net of tax) and an increase to Equity-Noncontrolling Interests of $733 million on the Consolidated Balance Sheet in 2013. The change in Equity-Noncontrolling Interests primarily represents the public unitholders’ share of the increase in SEP’s equity as a result of the issuance of additional units to Spectra Energy, less the effects of the resulting decrease in the public unitholders’ ownership percentage of SEP. Spectra Energy’s ownership in SEP increased as a result of the transaction.
	On November 3, 2014, Spectra Energy completed the second of three planned transactions related to the U.S Assets Dropdown. This transaction consisted of contributing an additional 24.95% ownership interest in SESH and the remaining 1% interest in Steckman Ridge to SEP. Consideration to Spectra Energy was approximately 4.3 million newly issued SEP common units. Also, in connection with this transaction, SEP issued approximately 86,000 of newly issued general partner units to Spectra Energy in exchange for the same amount of common units in order to maintain Spectra Energy’s 2% general partner interest in SEP. This transfer of assets between entities under common control resulted in a decrease to Additional Paid-in Capital of $29 million ($16 million net of tax) and an increase to Equity-Noncontrolling Interests of $29 million on the Consolidated Balance Sheet in 2014. The change in Equity-Noncontrolling Interests primarily represents the public unitholders’ share of the increase in SEP’s equity as a result of the issuance of additional units to Spectra Energy, less the effects of the resulting decrease in the public unitholders’ ownership percentage of SEP. Spectra Energy’s ownership in SEP increased as a result of the transaction.
	The remaining, and final, transaction related to the U.S. Assets Dropdown is expected to occur in November 2015, and will consist of Spectra Energy’s remaining 0.1% interest in SESH.
	The contributed assets provide transportation and storage of natural gas, crude oil, and natural gas liquids for customers in various regions of the U.S. and in Alberta, Canada. The contributed assets included in the U.S. Assets Dropdown, once the third closing is completed, will have consisted of:
	• a 100% ownership interest in Texas Eastern Transmission, LP (Texas Eastern)
	• a 100% ownership interest in Algonquin Gas Transmission, LLC (Algonquin)
	• Spectra Energy’s remaining 60% ownership interest in the U.S. portion of Express-Platte
	• Spectra Energy’s remaining 38.77% ownership interest in Maritimes & Northeast Pipeline, L.L.C. (M&N U.S.)
	• a 33.3% ownership interest in DCP Sand Hills Pipeline, LLC (Sand Hills)
	• a 33.3% ownership interest in DCP Southern Hills Pipeline, LLC (Southern Hills)
	• Spectra Energy’s remaining 1% ownership interest in Gulfstream Natural Gas System, LLC (Gulfstream)
	• a 50% ownership interest in SESH
	• a 100% ownership interest in Bobcat Gas Storage (Bobcat)
	• Spectra Energy’s remaining 50% of Market Hub Partners Holding (Market Hub)
	• a 50% ownership interest in Steckman Ridge
	• Texas Eastern’s and Express-Platte’s storage facilities
	Express-Platte. In August 2013, Spectra Energy contributed a 40% interest in the U.S. portion of Express-Platte and sold a 100% ownership interest in the Canadian portion to SEP. Aggregate consideration for the transactions consisted of $410 million in cash and 7.2 million of newly issued SEP partnership units. This transfer of assets between entities resulted in a decrease to Additional Paid-in Capital of $84 million ($53 million net of tax) and an increase to Equity-Noncontrolling Interest of $84 million. The change in Equity-Noncontrolling Interests primarily represents the public unitholders’ share of the increase in SEP equity as a result of the issuance of additional units to Spectra Energy, less the effects of the resulting decrease in the public unitholders’ ownership percentage.
	M&N U.S. In 2012, Spectra Energy transferred a 38.76% interest in M&N U.S. to SEP for approximately $375 million, consisting of approximately $319 million in cash and $56 million in newly issued partnership units. The price received by Spectra Energy exceeded the book value of the M&N U.S. investment. Therefore, this transfer of assets between entities resulted in an increase to Additional Paid-in Capital of $54 million ($34 million net of tax) and a decrease to Equity-Noncontrolling Interests of $54 million, representing the portion of the excess that was associated with the public unitholders’ of SEP.
	Sales of SEP Common Units. In November 2013, SEP entered into an equity distribution agreement under which it may sell and issue common units up to an aggregate amount of $400 million. This at-the-market program allows SEP to offer and sell its common units, representing limited partner interests, at prices it deems appropriate through a sales agent. Sales of common units, if any, will be made by means of ordinary brokers’ transactions on the New York Stock Exchange, in block transactions, or as otherwise agreed to between SEP and the sales agent. SEP intends to use the net proceeds from sales under the program for general partnership purposes, which may include debt repayment, future acquisitions, capital expenditures and additions to working capital. SEP issued 6.4 million common units to the public in 2014 under this program, for total net proceeds of $327 million, and 0.6 million common units in 2013, for total net proceeds of $24 million.
	In April 2013, SEP issued 5.2 million common units to the public, representing limited partner interests, and 0.1 million general partner units to Spectra Energy. Total net proceeds to SEP were $193 million (net proceeds to Spectra Energy were $190 million). Net proceeds to SEP were temporarily invested in restricted available-for-sale securities until the U.S. Assets Dropdown, at which time the funds were used to pay for a portion of the dropdown transaction. In connection with the sale of the units, a $61 million gain ($38 million net of tax) to Additional Paid-in Capital and a $128 million increase in Equity-Noncontrolling Interests were recorded in 2013.
	In 2012, SEP issued 5.5 million common units to the public, representing limited partner interests, and 0.1 million general partner units to Spectra Energy. Total net proceeds to SEP were $148 million (net proceeds to Spectra Energy were $145 million) and were restricted for the purpose of funding SEP’s capital expenditures and acquisitions. In connection with the sale of the units, a $42 million gain ($26 million net of tax) to Additional Paid-in Capital and a $108 million increase in Equity-Noncontrolling Interests were recorded in 2012.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Acquisitions and Dispositions	Acquisitions and Dispositions
	Acquisitions. We consolidate assets and liabilities from acquisitions as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date. Assets acquired and liabilities assumed are recorded at estimated fair values on the date of acquisition. The purchase price less the estimated fair value of the acquired assets and liabilities meeting the definition of a “business” is recorded as goodwill. The allocation of the purchase price may be adjusted if additional information is received during the allocation period, which generally does not exceed one year from the consummation date.
	Express-Platte. In March 2013, we acquired 100% of the ownership interests in the Express-Platte crude oil pipeline system for $1.5 billion, consisting of $1.25 billion in cash and $260 million of acquired debt, before working capital adjustments. The Express-Platte pipeline system, which begins in Hardisty, Alberta, and terminates in Wood River, Illinois, is comprised of both the Express and Platte crude oil pipelines. The Express pipeline carries crude oil to U.S. refining markets in the Rockies area, including Montana, Wyoming, Colorado and Utah. The Platte pipeline, which interconnects with Express pipeline in Casper, Wyoming, transports crude oil predominantly from the Bakken shale and western Canada to refineries in the Midwest. In 2013, subsidiaries of Spectra Energy contributed a 100% interest in the U.S. portion of Express-Platte and sold a 100% ownership interest in the Canadian portion to SEP. See Note 2 for further discussion.
	The following table summarizes the fair values of the assets and liabilities acquired as of the date of the acquisition.
		Purchase Price Allocation
		(in millions)
	Cash purchase price	$	1,250
	Working capital and other purchase adjustments	71
	Total	1,321
	Cash	67
	Receivables	25
	Other current assets	9
	Property, plant and equipment	1,251
	Accounts payable	(18		)
	Other current liabilities	(17		)
	Deferred credits and other liabilities	(259		)
	Long-term debt, including current portion	(260		)
	Total assets acquired/liabilities assumed	798
	Goodwill	$	523
	The purchase price is greater than the sum of fair values of the net assets acquired, resulting in goodwill as noted above. The goodwill reflects the value of the strategic location of the pipeline and the opportunity to grow the business. Goodwill related to the acquisition of Express-Platte is not deductible for income tax purposes.
	The allocation of the fair values of assets and liabilities acquired related to the acquisition of Express-Platte was finalized in the first quarter of 2014, resulting in the following adjustments to amounts reported as of December 31, 2013: a $60 million decrease in Property, Plant and Equipment, a $1 million decrease in Other Current Assets and a $24 million decrease in Deferred Credits and Other Liabilities, resulting in a $37 million increase in Goodwill.
	Sand Hills and Southern Hills. In 2012, Spectra Energy acquired direct one-third ownership interests in Sand Hills and Southern Hills NGL pipelines from DCP Midstream for an aggregate $459 million, both of which were placed in service during the second quarter of 2013. DCP Partners, DCP Midstream’s master limited partnership, and Phillips 66 also each own direct one-third ownership interests in the two pipelines. The Sand Hills pipeline provides NGL transportation from the Permian and Eagle Ford basins to the premium NGL markets on the Gulf Coast. The Southern Hills pipeline provides NGL transportation from the Midcontinent to Mont Belvieu, Texas. In November 2013, subsidiaries of Spectra Energy contributed their 33% direct interests in Sand Hills and Southern Hills to SEP in connection with the U.S. Assets Dropdown. See Note 2 for further discussion. Our investments in Sand Hills and Southern Hills are included in Investments in and Loans to Unconsolidated Affiliates on our Consolidated Balance Sheets and Statements of Cash Flows.
	Pro forma results of operations reflecting these acquisitions as if the acquisitions had occurred as of the beginning of the periods presented in this report do not materially differ from actual results reported in our Consolidated Statements of Operations.

Business_Segments

Business Segments	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Business Segments	Business Segments
	We manage our business in four reportable segments: Spectra Energy Partners, Distribution, Western Canada Transmission & Processing and Field Services. The remainder of our business operations is presented as “Other,” and consists of unallocated corporate costs and employee benefit plan assets and liabilities, 100%-owned captive insurance subsidiaries and other miscellaneous activities.
	Our chief operating decision maker (CODM) regularly reviews financial information about each of these segments in deciding how to allocate resources and evaluate performance. There is no aggregation within our reportable business segments.
	The presentation of our Spectra Energy Partners segment is reflective of the parent-level focus by our CODM, considering the resource allocation and governance provisions associated with SEP’s master limited partnership structure. SEP maintains a capital and cash management structure that is separate from Spectra Energy’s, is self-funding and maintains its own lines of bank credit and cash management accounts. It is in this context that our CODM evaluates the Spectra Energy Partners segment as a whole, without regard to any of SEP’s individual businesses. These factors, coupled with a different cost of capital of our other businesses, serve to differentiate how our Spectra Energy Partners segment is managed as compared to how SEP is managed.
	Spectra Energy Partners provides transmission, storage and gathering of natural gas, as well as the transportation of crude oil and NGLs through interstate pipeline systems for customers in various regions of the midwestern, northeastern and southeastern United States and Canada. The natural gas transmission and storage operations are primarily subject to the rules and regulations of the Federal Energy Regulatory Commission (FERC). The crude oil transportation operations are primarily subject to regulation by the FERC in the U.S. and the National Energy Board (NEB) in Canada. Our Spectra Energy Partners segment is composed of the operations of SEP, less governance costs, which are included in “Other.”
	Distribution provides retail natural gas distribution service in Ontario, Canada, as well as natural gas transmission and storage services to other utilities and energy market participants. These services are provided by Union Gas Limited (Union Gas), and are primarily subject to the rules and regulations of the OEB.
	Western Canada Transmission & Processing provides transmission of natural gas, natural gas gathering and processing services, and NGL extraction, fractionation, transportation, storage and marketing to customers in western Canada, the northern tier of the United States and the Maritime Provinces in Canada. This segment conducts business mostly through BC Pipeline, BC Field Services, and the NGL marketing and Canadian Midstream businesses, and Maritimes & Northeast Pipeline Limited Partnership (M&N Canada). BC Pipeline and BC Field Services and M&N Canada operations are primarily subject to the rules and regulations of the NEB.
	Field Services gathers, compresses, treats, processes, transports, stores and sells natural gas, produces, fractionates, transports, stores and sells NGLs, recovers and sells condensate, and trades and markets natural gas and NGLs. It conducts operations through DCP Midstream, which is owned 50% by us and 50% by Phillips 66. DCP Midstream gathers raw natural gas through gathering systems connecting to several interstate and intrastate natural gas NGL pipeline systems, one natural gas storage facility and one NGL storage facility. DCP Midstream operates in a diverse number of regions, including the Permian Basin, Eagle Ford, Niobrara/DJ Basin and the Midcontinent. DCP Midstream Partners, LP (DCP Partners) is a publicly traded master limited partnership, of which DCP Midstream acts as general partner. As of December 31, 2014, DCP Midstream had an approximate 22% ownership interest in DCP Partners, including DCP Midstream’s limited partner and general partner interests.
	Our reportable segments offer different products and services and are managed separately as business units. Management evaluates segment performance based on earnings from continuing operations before interest, taxes, depreciation and amortization (EBITDA). Cash, cash equivalents and short-term investments are managed at the parent-company levels, so the associated gains and losses from foreign currency transactions and interest and dividend income are excluded from the segments’ EBITDA. Our segment EBITDA may not be comparable to similarly titled measures of other companies because other companies may not calculate EBITDA in the same manner. Transactions between reportable segments are accounted for on the same basis as transactions with unaffiliated third parties.
	Business Segment Data
		Unaffiliated Revenues		Intersegment			Total			Segment EBITDA/			Depreciation		Capital and		Assets
				Revenues			Operating			Consolidated			and		Investment
							Revenues (a)			Earnings			Amortization (a)		Expenditures (b,c)
										from Continuing
										Operations before
										Income Taxes (a)
		(in millions)
	2014
	Spectra Energy Partners	$	2,269	$	—		$	2,269		$	1,669		$	290	$	1,241	$	17,865
	Distribution	1,843		—			1,843			552			192		427		6,064
	Western Canada Transmission & Processing	1,781		121			1,902			754			271		473		6,916
	Field Services	—		—			—			217			—		—		1,345
	Total reportable segments	5,893		121			6,014			3,192			753		2,141		32,190
	Other	10		62			72			(58		)	43		146		1,908
	Eliminations	—		(183		)	(183		)	—			—		—		(58		)
	Depreciation and amortization	—		—			—			796			—		—		—
	Interest expense	—		—			—			679			—		—		—
	Interest income and other	—		—			—			6			—		—		—
	Total consolidated	$	5,903	$	—		$	5,903		$	1,665		$	796	$	2,287	$	34,040
	2013
	Spectra Energy Partners	$	1,964	$	1		$	1,965		$	1,433		$	263	$	1,299	$	16,800
	Distribution	1,848		—			1,848			574			199		357		6,009
	Western Canada Transmission & Processing	1,694		73			1,767			736			272		561		7,160
	Field Services	—		—			—			343			—		—		1,365
	Total reportable segments	5,506		74			5,580			3,086			734		2,217		31,334
	Other	12		60			72			(86		)	38		42		2,698
	Eliminations	—		(134		)	(134		)	—			—		—		(499		)
	Depreciation and amortization	—		—			—			772			—		—		—
	Interest expense	—		—			—			657			—		—		—
	Interest income and other	—		—			—			7			—		—		—
	Total consolidated	$	5,518	$	—		$	5,518		$	1,578		$	772	$	2,259	$	33,533
	2012
	Spectra Energy Partners	$	1,754	$	—		$	1,754		$	1,259		$	232	$	1,443	$	13,856
	Distribution	1,666		—			1,666			587			213		276		5,842
	Western Canada Transmission & Processing	1,645		34			1,679			694			245		760		7,226
	Field Services	—		—			—			279			—		—		1,235
	Total reportable segments	5,065		34			5,099			2,819			690		2,479		28,159
	Other	10		79			89			(36		)	56		66		2,967
	Eliminations	—		(113		)	(113		)	—			—		—		(539		)
	Depreciation and amortization	—		—			—			746			—		—		—
	Interest expense	—		—			—			625			—		—		—
	Interest income and other	—		—			—			3			—		—		—
	Total consolidated	$	5,075	$	—		$	5,075		$	1,415		$	746	$	2,545	$	30,587
	__________
	(a)	Excludes amounts associated with entities included in discontinued operations.
	(b)	Excludes the $1,254 million cash outlay for the acquisition of Express-Platte in March 2013 and $30 million paid in 2012 for amounts previously withheld from the purchase price consideration of the acquisition of Bobcat in 2010, all part of Spectra Energy Partners.
	(c)	Excludes a $71 million loan to an unconsolidated affiliate in 2013 at Spectra Energy Partners.
	Geographic Data
		U.S.		Canada			Consolidated
		(in millions)
	2014
	Consolidated revenues	$	2,212	$	3,691		$	5,903
	Consolidated long-lived assets	15,859		12,732			28,591
	2013
Consolidated revenues	1,926		3,592			5,518
Consolidated long-lived assets	14,993		13,264			28,257
2012
Consolidated revenues (a)	1,762		3,313			5,075
Consolidated long-lived assets	10,952		14,875			25,827
__________
(a)	Excludes revenues associated with businesses included in discontinued operations.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2014
Regulated Operations [Abstract]
Regulatory Matters	Regulatory Matters
	Regulatory Assets and Liabilities
	We record assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities. See Note 1 for further discussion.
		December 31,				Recovery/
						Refund
		2014		2013		Period Ends
		(in millions)
	Regulatory Assets (a,b)
	Net regulatory asset related to income taxes (c,d)	$	1,271	$	1,224	(e)
	Project development costs	10		14		2036
	Vacation accrual	22		21		(f)
	Deferred debt expense/premium (d)	31		32		(e)
	Under-recovery of fuel costs (g,h)	44		28		2015
	Gas purchase costs (h,i)	57		—		2015
	Other	59		57		(j)
	Total Regulatory Assets	$	1,494	$	1,376
	Regulatory Liabilities (b)
	Removal costs (d,k)	$	326	$	359	(l)
	FT-RAM optimization (m)	—		31		2014
	Gas purchase costs (i,m)	—		7		2014
	Pipeline rate credit (k)	25		27		(e)
	Over-recovery of fuel costs (i,m)	—		35		2014
	Other (d)	79		51		(j)
	Total Regulatory Liabilities	$	430	$	510
	_________
	(a)	Included in Regulatory Assets and Deferred Debits unless otherwise noted.
	(b)	All regulatory assets and liabilities are excluded from rate base unless otherwise noted.
	(c)	All amounts are expected to be included in future rate filings.
	(d)	All or a portion of the balance is included in rate base.
	(e)	Recovery/refund is over the life of the associated asset or liability.
	(f)	Recoverable in future periods.
	(g)	Amounts settled in cash annually through transportation rates in accordance with FERC gas tariffs.
	(h)	Included in Other Current Assets.
	(i)	Includes certain costs which are settled in cash annually through transportation rates in accordance with FERC and/or OEB gas tariffs.
	(j)	The majority of this balance has a recovery period of less than one year. The recovery/refund period for the remainder is currently unknown.
	(k)	Included in Deferred Credits and Other Liabilities — Regulatory and Other.
	(l)	Liability is extinguished as the associated assets are retired.
	(m)	Included in Other Current Liabilities.
	Union Gas. Union Gas has regulatory assets of $303 million as of December 31, 2014 and $308 million as of December 31, 2013 related to deferred income tax liabilities. Under the current OEB-authorized rate structure, income tax costs are recovered in rates based on the current income tax payable and do not include accruals for deferred income tax. However, as income taxes become payable as a result of the reversal of timing differences that created the deferred income taxes, it is expected that rates will be adjusted to recover these taxes. Since substantially all of these timing differences are related to property, plant and equipment costs, recovery of these regulatory assets is expected to occur over the life of those assets.
	Union Gas has regulatory liabilities associated with plant removal costs of $322 million as of December 31, 2014 and $354 million as of December 31, 2013. These regulatory liabilities represent collections from customers under approved rates for future asset removal activities that are expected to occur associated with its regulated facilities.
	In addition, Union Gas has regulatory assets of $57 million as of December 31, 2014 and regulatory liabilities of $7 million as of December 31, 2013 representing gas cost collections from customers under approved rates that vary from actual cost of gas for the associated periods. Union Gas files an application quarterly with the OEB to ensure that customers’ rates are updated to reflect published forward-market prices. The difference between the approved and the actual cost of gas is deferred for future repayment to or refund from customers.
	BC Pipeline and BC Field Services. The BC Pipeline and BC Field Services businesses in western Canada have regulatory assets of $795 million as of December 31, 2014 and $774 million as of December 31, 2013 related to deferred income tax liabilities. Under the current NEB-authorized rate structure, income tax costs are recovered in tolls based on the current income tax payable and do not include accruals for deferred income tax. However, as income taxes become payable as a result of the reversal of timing differences that created the deferred income taxes, it is expected that transportation and field services tolls will be adjusted to recover these taxes. Since most of these timing differences are related to property, plant and equipment costs, this recovery is expected to occur over a 20 to 30 year period.
	When evaluating the recoverability of the BC Pipelines’ and BC Field Services’ regulatory assets, we take into consideration the NEB regulatory environment, natural gas reserve estimates for reserves located or expected to be located near these assets, the ability to remain competitive in the markets served and projected demand growth estimates for the areas served by the BC Pipeline and BC Field Services businesses. Based on current evaluation of these factors, we believe that recovery of these tax costs is probable over the periods described above.
	Rate Related Information
	Union Gas.  In 2012, the OEB determined that revenues derived from the optimization of Union Gas’ upstream transportation contracts in 2011 would be treated as a reduction to gas costs rather than being treated as optimization revenues and included in utility earnings. Optimization revenues had been classified as utility earnings for 2008, 2009, 2010, and subsequently 2012, as described in the following paragraph. This decision was appealed to the Ontario Divisional Court on the basis of impermissible retroactive ratemaking. The appeal was dismissed in December 2013. In May 2014, Union Gas filed a notice of appeal to the Ontario Court of Appeal and a hearing was held in December 2014. A decision from the Ontario Court of Appeal is expected in 2015.
	Union Gas filed an application with the OEB in May 2013 for the annual disposition of the 2012 deferral account balances. A decision on that application was issued by the OEB in March 2014. Among other things, the OEB determined that revenues derived from the optimization of Union Gas’ upstream transportation contracts in 2012 will be treated as revenues and included in utility earnings rather than as a reduction to gas costs. The decision also denied a proposal to recover certain over-refunds to customers and reduced incentive amounts related to Union Gas’ 2011 energy conservation program. As a result of this OEB decision, Union Gas recognized pre-tax income of $10 million in the first quarter of 2014, comprised of a $32 million increase in Transportation, Storage and Processing of Natural Gas revenues, a $15 million decrease in Distribution of Natural Gas revenues and a $7 million decrease in Other revenues on the Consolidated Statements of Operations. In addition, the decision approved the deferral of pension expense for recovery from customers, resulting in pre-tax income of $7 million, recorded as a reduction in Operating, Maintenance and Other expense in the second quarter of 2014.
	In May 2014, Union Gas filed an application with the OEB for the annual disposition of its 2013 deferral account balances, excluding the energy conservation deferral accounts. The combined impact of the 2013 deferral account balances is a net payable to customers of approximately $19 million which is primarily reflected as Current Liabilities—Other on the Consolidated Balance Sheets at December 31, 2014 and 2013. In October 2014, the OEB approved the balances with no significant impact to the amounts filed. The net payable to customers is being refunded over a six month period that began January 1, 2015.
	In December 2014, Union Gas filed an application with the OEB for the disposition of the 2013 energy conservation deferral and variance account balances. As a result of this application, Union Gas has a receivable from customers of approximately $9 million. A hearing and decision from the OEB is expected in 2015.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Income Tax Expense Components
		2014			2013			2012
		(in millions)
	Current income taxes
	Federal	$	1		$	(32	)	$	102
	State	3			4			5
	Foreign	(10		)	26			52
	Total current income taxes	(6		)	(2		)	159
	Deferred income taxes
	Federal	335			353			174
	State	(17		)	69			33
	Foreign	70			(1		)	4
	Total deferred income taxes	388			421			211
	Income tax expense from continuing operations	382			419			370
	Income tax expense from discontinued operations	—			—			2
	Total income tax expense	$	382		$	419		$	372
	Earnings from Continuing Operations before Income Taxes
		2014			2013			2012
		(in millions)
	Domestic	$	1,108		$	1,059		$	912
	Foreign	557			519			503
	Total earnings from continuing operations before income taxes	$	1,665		$	1,578		$	1,415
	Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to Actual Income Tax Expense from Continuing Operations
		2014			2013			2012
		(in millions)
	Income tax expense, computed at the statutory rate of 35%	$	583		$	552		$	495
	State income tax, net of federal income tax effect	25			20			19
	Tax differential on foreign earnings	(125		)	(147		)	(110		)
	Noncontrolling interests	(70		)	(42		)	(37		)
	Valuation allowance	2			(3		)	1
	Revaluation of accumulated deferred state taxes	(25		)	31			—
	Other items, net	(8		)	8			2
	Total income tax expense from continuing operations	$	382		$	419		$	370
	Effective tax rate	22.9		%	26.6		%	26.1		%
	Net Deferred Income Tax Liability Components
		December 31,
		2014			2013
		(in millions)
	Deferred credits and other liabilities	$	225		$	242
	Other	211			291
	Total deferred income tax assets	436			533
	Valuation allowance	(29		)	(29		)
	Net deferred income tax assets	407			504
	Investments and other assets	(1,531		)	(1,004		)
	Accelerated depreciation rates	(3,875		)	(4,092		)
	Regulatory assets and deferred debits	(426		)	(383		)
	Total deferred income tax liabilities	(5,832		)	(5,479		)
	Total net deferred income tax liabilities	$	(5,425	)	$	(4,975	)
	The above deferred tax amounts have been classified in the Consolidated Balance Sheets as follows:
		December 31,
		2014			2013
		(in millions)
	Other current assets	$	—		$	9
	Other current liabilities	(20		)	(16		)
	Deferred credits and other liabilities	(5,405		)	(4,968		)
	Total net deferred income tax liabilities	$	(5,425	)	$	(4,975	)
	At December 31, 2014, we had a federal net operating loss carryforward of $379 million that expires at various times beginning in 2021. The deferred tax asset attributable to the federal net operating loss is $133 million. At December 31, 2014 we also had a state net operating loss carryforward of approximately $299 million that expires at various times beginning in 2016. The deferred tax asset attributable to the state net operating loss carryovers is $15 million (net of federal impacts) at December 31, 2014. We had valuation allowances of $9 million at December 31, 2014 and $7 million at December 31, 2013 against the deferred tax asset related to the federal net operating loss carryforward.
	At December 31, 2014, we had a foreign net operating loss carryforward of $40 million that expires at various times beginning in 2015. The deferred tax asset attributable to the foreign net operating loss is $10 million. At December 31, 2014, we also had a foreign capital loss carryforward of $151 million with an indefinite expiration period. The deferred tax asset attributable to the foreign capital loss carryforward is $20 million. We had valuation allowances of $20 million and $22 million at December 31, 2014 and 2013, respectively, against the deferred tax asset related to the foreign capital loss carryforward.
	Reconciliation of Gross Unrecognized Income Tax Benefits
		2014			2013			2012
		(in millions)
	Balance at beginning of period	$	76		$	80		$	76
	Increases related to prior year tax positions	10			7			5
Decreases related to prior year tax positions	(6		)	(17		)	—
Increases related to current year tax positions	1			2			2
Settlements	—			(3		)	(2		)
Lapse of statute of limitations	(30		)	9			(2		)
Foreign currency translation	(1		)	(2		)	1
Balance at end of period	$	50		$	76		$	80
Unrecognized tax benefits totaled $50 million at December 31, 2014. Of this, $33 million would reduce the annual effective tax rate if recognized on or after January 1, 2015. We recorded a net decrease of $26 million in gross unrecognized tax benefits during 2014. This was a result of $27 million attributable to deferred tax liabilities and foreign currency exchange rate fluctuations offset by a $1 million increase in income tax expense.
We recognize potential accrued interest and penalties related to unrecognized tax benefits as interest expense and as other expense, respectively. We recognized interest income of $2 million in 2014 and $4 million in 2013 related to unrecognized tax benefits. Accrued interest and penalties totaled $19 million at December 31, 2014 and $21 million at December 31, 2013.
Although uncertain, we believe it is reasonably possible that the total amount of unrecognized tax benefits could decrease by $15 million to $20 million prior to December 31, 2015.
We remain subject to examination for Canada income tax return filings for years 2009 through 2013 and U.S. income tax return filings for 2007 through 2013.
We have foreign subsidiaries’ undistributed earnings of approximately $1.8 billion at December 31, 2014 that are indefinitely invested outside the United States and, accordingly, no U.S. federal or state income taxes have been provided on those earnings. Upon distribution of those earnings, we may be subject to both foreign withholding taxes and U.S. income taxes, net of allowable foreign tax credits. The amount of such additional taxes would be dependent on several factors, including the size and timing of the distribution and the availability of foreign tax credits. As a result, the determination of the potential amount of unrecognized withholding and deferred income taxes is not practicable.
In September 2013, the U.S. Treasury and the Internal Revenue Service (IRS) issued final regulations regarding the deduction and capitalization of expenditures related to tangible property (tangible property regulations). The final IRS regulations apply to amounts paid to acquire, produce or improve tangible property as well as dispositions of such property and are for tax years beginning on or after January 1, 2014. The tangible property regulations impact the timing of the deductibility of these expenditures for tax purposes and therefore the impact resulted in an increase in our future tax liability with a corresponding increase in our net operating loss carryforward. Our earnings will not be impacted.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations
	Discontinued operations in 2012 were mostly comprised of the net effects of a settlement arrangement related to prior liquefied natural gas (LNG) contracts.
	The following table summarizes results classified as Income From Discontinued Operations, Net of Tax in the accompanying Consolidated Statements of Operations:
		2012
		(in millions)
	Operating revenues	$	99
	Pre-tax earnings	4
	Income tax expense	2
	Income from discontinued operations, net of tax	2
	Spectra Energy LNG Sales, Inc. (Spectra Energy LNG) reached a settlement agreement in 2007 related to an arbitration proceeding regarding Spectra Energy LNG’s claims for the period prior to May 2002 under certain liquefied natural gas LNG transportation contracts with Sonatrach and Sonatrading Amsterdam B.V. (Sonatrach). Spectra Energy LNG was one of the entities contributed to us by Duke Energy in connection with our spin-off from Duke Energy and has been reflected as discontinued operations. In 2008, Sonatrach and Spectra Energy entered into a settlement agreement under which Spectra Energy LNG’s claims for the period after May 2002 were to be satisfied pursuant to commercial transactions involving the purchase of propane by Spectra Energy Propane, LLC (a subsidiary) from Sonatrach. We subsequently entered into associated agreements with what are now affiliates of DCP Midstream for the sale of this propane. Net purchases and sales of propane under these arrangements are reflected as discontinued operations within the “Other” business segment. Purchases and sales of propane under these agreements ended in 2012.

Earnings_per_Common_Share

Earnings per Common Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings per Common Share	Earnings per Common Share
	Basic earnings per common share (EPS) is computed by dividing net income from controlling interests by the weighted-average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income from controlling interests by the diluted weighted-average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options, stock-based performance unit awards and phantom stock awards, were exercised, settled or converted into common stock.
	Weighted-average shares used to calculate diluted EPS includes the effect of certain options and restricted stock awards. In 2014 and 2013, there were no options or stock awards that were not included in the calculation of diluted EPS. Certain other options and stock awards related to less than one million shares in 2012 were not included in the calculation of diluted EPS because either the option exercise prices were greater than the average market price of the shares or performance measures related to the awards had not yet been met.
	The following table presents our basic and diluted EPS calculations:
		2014		2013		2012
		(in millions, except per-share amounts)
	Income from continuing operations, net of tax — controlling interests	$	1,082	$	1,038	$	938
	Income from discontinued operations, net of tax — controlling interests	—		—		2
	Net income — controlling interests	$	1,082	$	1,038	$	940
	Weighted-average common shares outstanding
	Basic	671		669		653
	Diluted	672		671		656
	Basic earnings per common share	$	1.61	$	1.55	$	1.44
	Diluted earnings per common share	$	1.61	$	1.55	$	1.43
	Income from discontinued operations in 2012 had no effect on basic or diluted EPS.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Income
	The following table presents the net of tax changes in AOCI by component and amounts reclassified out of AOCI to Net Income, excluding amounts attributable to noncontrolling interests:
		Foreign Currency Translation Adjustments			Pension and Post-retirement Benefit Plan Obligations				Gas Purchase Contract Hedges			Other			Total Accumulated Other Comprehensive Income
								(in millions)
	31-Dec-12	$	2,044		$	(507	)		$	(23	)	$	(5	)	$	1,509
	Reclassified to net income	—			—				6			1			7
	Other AOCI activity	(487		)	203				6			3			(275		)
	31-Dec-13	1,557			(304		)		(11		)	(1		)	1,241
	Reclassified to net income	—			—				4			1			5
	Other AOCI activity	(541		)	(47		)		4			—			(584		)
	31-Dec-14	$	1,016		$	(351	)		$	(3	)	$	—		$	662
	Reclassifications to Net Income are primarily included in Other Income and Expenses, Net on our Consolidated Statements of Operations.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventory	Inventory
	The components of inventory are as follows:
		December 31,
		2014		2013
		(in millions)
	Natural gas	$	211	$	155
	NGLs	28		30
	Materials and supplies	74		78
	Total inventory	$	313	$	263
	Non-cash charges totaling $19 million in 2014 ($14 million after tax) were recorded to Natural Gas and Petroleum Products Purchased on the Consolidated Statements of Operations to reduce propane inventory at our Empress operations at Western Canada Transmission & Processing to estimated net realizable value. There were no non-cash charges to inventory in 2013.

Investments_in_and_Loans_to_Un

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Investments in and Advances to Affiliates, Schedule of Investments [Abstract]
Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions	Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions
	Investments in affiliates for which we are not the primary beneficiary, but over which we have significant influence, are accounted for using the equity method. As of December 31, 2014 and 2013, the carrying amounts of investments in affiliates approximated the amounts of underlying equity in net assets. We received distributions from our equity investments of $646 million in 2014, $411 million in 2013 and $324 million in 2012. Cumulative undistributed earnings of unconsolidated affiliates totaled $482 million at December 31, 2014 and $507 million at December 31, 2013.
	Spectra Energy Partners. As of December 31, 2014, our Spectra Energy Partners segment investments were mostly comprised of a 41% effective interest in Gulfstream, a 41% effective interest in SESH, a 41% effective interest in Steckman Ridge and 27% effective interests in Sand Hills and Southern Hills. Our remaining 0.1% interest in SESH is currently held in “Other” and is expected to be contributed in November 2015. We also own additional 4% effective interests in Sand Hills and Southern Hills through our ownership interest in DCP Midstream, which is held in our Field Services segment.
	We have a loan outstanding to Steckman Ridge in connection with the construction of its storage facilities. The loan carries market-based interest rates and is due the earlier of October 1, 2023 or coincident with the closing of any long-term financings by Steckman Ridge. The loan receivable from Steckman Ridge, including accrued interest, totaled $71 million at both December 31, 2014 and 2013. We recorded interest income on the Steckman Ridge loan of $1 million in each of 2014, 2013 and 2012. In conjunction with the U.S. Assets Dropdown in November 2013, Steckman Ridge repaid the loan to a subsidiary of Spectra Energy Corp and subsequently borrowed $71 million directly from SEP.
	Field Services. Our most significant investment in unconsolidated affiliates is our 50% investment in DCP Midstream, which is accounted for under the equity method of accounting. DCP Partners, DCP Midstream’s master limited partnership, also has direct one-third equity investments in Sand Hills and Southern Hills. DCP Midstream is a limited liability company which is a pass-through entity for U.S. income tax purposes. DCP Midstream also owns an entity which files its own federal, foreign and state income tax returns. Income tax expense related to that entity is included in the income tax expense of DCP Midstream. Therefore, DCP Midstream’s net income attributable to members’ interests does not include income taxes for earnings which are passed through to the members based upon their ownership percentage. We recognize the tax effects of our share of DCP Midstream’s pass-through earnings in Income Tax Expense from Continuing Operations in the Consolidated Statements of Operations.
	DCP Partners issues, from time to time, limited partner units to the public, which are recorded by DCP Midstream directly to its equity. Our proportionate 50% share of gains from those issuances, totaling $73 million in 2014, $98 million in 2013 and $36 million in 2012, are reflected in Equity in Earnings of Unconsolidated Affiliates in the Consolidated Statements of Operations.
	Investments in and Loans to Unconsolidated Affiliates
		31-Dec-14									31-Dec-13
		Domestic			International			Total			Domestic			International			Total
		(in millions)
	Spectra Energy Partners	$	1,588		$	—		$	1,588		$	1,396		$	—		$	1,396
	Distribution	—			14			14			—			16			16
	Western Canada Transmission & Processing	—			18			18			—			66			66
	Field Services	1,345			—			1,345			1,365			—			1,365
	Other	1			—			1			200			—			200
	Total	$	2,934		$	32		$	2,966		$	2,961		$	82		$	3,043
	Equity in Earnings of Unconsolidated Affiliates
		2014									2013									2012
		Domestic			International			Total			Domestic			International			Total			Domestic		International		Total
		(in millions)
	Spectra Energy Partners	$	133		$	—		$	133		$	90		$	—		$	90		$	89	$	—	$	89
	Distribution	—			1			1			—			1			1			—		—		—
	Western Canada Transmission & Processing	—			1			1			—			(1		)	(1		)	—		1		1
	Field Services	217			—			217			343			—			343			279		—		279
	Other	9			—			9			12			—			12			13		—		13
	Total	$	359		$	2		$	361		$	445		$	—		$	445		$	381	$	1	$	382
	Summarized Combined Financial Information of Unconsolidated Affiliates (Presented at 100%)
	Statements of Operations
		2014									2013									2012
		DCP			Other			Total			DCP			Other			Total			DCP		Other		Total
		Midstream									Midstream									Midstream
		(in millions)
	Operating revenues	$	14,013		$	744		$	14,757		$	12,038		$	558		$	12,596		$	10,171	$	511	$	10,682
	Operating expenses	13,262			319			13,581			11,230			261			11,491			9,427		217		9,644
	Operating income	751			425			1,176			808			297			1,105			744		294		1,038
	Net income	536			332			868			584			206			790			583		203		786
	Net income attributable to members’  interests	288			332			620			491			206			697			486		203		689
	Balance Sheets
		31-Dec-14									31-Dec-13
		DCP			Other			Total			DCP			Other			Total
		Midstream									Midstream
		(in millions)
	Current assets	$	1,380		$	241		$	1,621		$	1,663		$	248		$	1,911
	Non-current assets	12,299			5,358			17,657			11,058			5,448			16,506
	Current liabilities	(2,938		)	(632		)	(3,570		)	(3,114		)	(143		)	(3,257		)
	Non-current liabilities	(5,538		)	(1,197		)	(6,735		)	(5,218		)	(1,670		)	(6,888		)
	Equity — total	5,203			3,770			8,973			4,389			3,883			8,272
	Equity — noncontrolling interests	(2,578		)	—			(2,578		)	(1,725		)	—			(1,725		)
	Equity — controlling interests	$	2,625		$	3,770		$	6,395		$	2,664		$	3,883		$	6,547
	Related Party Transactions
	DCP Midstream. DCP Midstream processes certain of our pipeline customers’ gas to meet gas quality specifications in order to be transported on our Texas Eastern system. DCP Midstream processes the gas and sells the NGLs that are extracted from the gas. A portion of the proceeds from those sales are retained by DCP Midstream and the balance is remitted to us. We received proceeds of $79 million in 2014, $48 million in 2013 and $53 million in 2012 from DCP Midstream related to those sales, classified as Other Operating Revenues in our Consolidated Statements of Operations.
	As discussed in Note 7, we entered into a propane sales agreement with an affiliate of DCP Midstream in 2008. We recorded revenues of $99 million in 2012 associated with this agreement classified within Income From Discontinued Operations, Net of Tax. Sales of propane under this agreement ended in 2012.
	In addition to the above, we recorded other revenues from DCP Midstream and its affiliates totaling $9 million in 2014 and 2013 and $12 million in 2012, primarily within Transportation, Storage and Processing of Natural Gas, and $7 million in 2014, $8 million in 2013 and $14 million in 2012 within Sales of Natural Gas Liquids.
	We had accounts receivable from DCP Midstream and its affiliates of $1 million at December 31, 2014 and December 31, 2013. Total distributions received from DCP Midstream were $237 million in 2014, $215 million in 2013 and $203 million in 2012, classified as Cash Flows from Operating Activities — Distributions Received From Unconsolidated Affiliates.
	In 2012, we acquired direct one-third ownership interests in Sand Hills and Southern Hills from DCP Midstream for $459 million. See Notes 2 and 3 for further discussion.
	Other. We provide certain administrative and other services to certain other operating entities. We recorded recoveries of costs from these affiliates of $38 million in 2014, $68 million in 2013 and $70 million in 2012. Outstanding receivables from these affiliates totaled $1 million at December 31, 2014 and $23 million at December 31, 2013.
	See also Notes 3, 17 and 19 for additional related party information.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill
	The following table presents activity within goodwill based on the reporting unit determination:
		Spectra Energy Partners			Distribution			Western Canada			Total
								Transmission &
								Processing
		(in millions)
	31-Dec-12	$	2,814		$	878		$	821		$	4,513
	Acquisition of Express-Platte	486			—			—			486
	Foreign currency translation	(85		)	(54		)	(50		)	(189		)
	31-Dec-13	3,215			824			771			4,810
	Adjustment to acquisition of Express-Platte	37			—			—			37
	Foreign currency translation	(8		)	(65		)	(60		)	(133		)
	31-Dec-14	$	3,244		$	759		$	711		$	4,714
	________
	See Note 3 for discussion of the acquisition of Express-Platte and an adjustment to Goodwill recorded in the first quarter of 2014 related to the acquisition.
	The following remaining goodwill amounts originating from the acquisition of Westcoast Energy, Inc. (Westcoast) in 2002 are included as segment assets within “Other” in the segment data presented in Note 4:
		December 31,
		2014			2013
		(in millions)
	Distribution	$	757		$	821
	Western Canada Transmission & Processing	677			736
	Certain commodity prices, specifically NGLs, have fluctuated in 2013 and 2014. Within the Western Canada Transmission & Processing segment, our Empress NGL business is significantly affected by fluctuations in commodity prices. NGL prices have significantly declined in the fourth quarter of 2014 from levels earlier in 2014. Effective January 2014, we implemented a commodity hedging program at Empress to economically hedge a significant portion of their future NGL sales and related make-up gas purchases, which has mitigated the effects of short-term commodity price fluctuations. This hedging program is designed to reduce cash inflow volatility despite year to year earnings volatility. A sustained decline in NGL prices would reduce earnings and potentially serve as a triggering event to test goodwill for impairment at the Empress NGL reporting unit, which could result in an impairment.

Marketable_Securities_and_Rest

Marketable Securities and Restricted Funds	12 Months Ended
	Dec. 31, 2014
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, bankers acceptances, corporate debt securities, treasury bills and money market funds in the United States and Canada. We do not purchase marketable securities for speculative purposes, therefore we do not have any securities classified as trading securities. While we do not routinely sell marketable securities prior to their scheduled maturity dates, some of our investments may be held and restricted for insurance purposes, so these investments are classified as 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 HTM marketable securities). Maturities of securities are classified within proceeds from sales and maturities of securities in the Consolidated Statements of Cash Flows.
	AFS Securities. AFS securities are as follows:
		Estimated Fair Value
		December 31,
		2014			2013
		(in millions)
	Corporate debt securities	$	23		$	18
	Money market funds	1			1
	Total available-for-sale securities	$	24		$	19
	Our AFS securities are classified on the Consolidated Balance Sheets as follows:
			Estimated Fair Value
			December 31,
			2014			2013
			(in millions)
	Restricted funds
	Investments and other assets—other		$	1		$	1
	Non-restricted funds
	Current assets—other		3			7
	Investments and other assets—other		20			11
	Total available-for-sale securities		$	24		$	19
	During the second quarter of 2013, we invested the proceeds from SEP’s issuance of common units in AFS marketable securities, which were restricted for the purpose of funding SEP’s future capital expenditures and acquisitions. In September 2013, we invested the net proceeds from SEP’s $1.9 billion issuance of long-term debt in AFS marketable securities, which were restricted for the purpose of paying a portion of the cash consideration for Spectra Energy’s U.S. Assets Dropdown to SEP. These investments and SEP’s other remaining restricted funds held for the purpose of funding capital expenditures and acquisitions were used to pay Spectra Energy for the U.S. Assets Dropdown on November 1, 2013.
	At December 31, 2014, the weighted–average contractual maturity of outstanding AFS securities was less than two years.
	There were no material gross unrealized holding gains or losses associated with investments in AFS securities at December 31, 2014 or 2013.
	HTM Securities. All of our HTM securities are restricted funds and are as follows:
			Estimated Fair Value
			December 31,
	Description	Consolidated Balance Sheet Caption	2014			2013
			(in millions)
	Bankers acceptances	Current assets—other	$	38		$	35
	Canadian government securities	Current assets—other	30			34
	Money market funds	Current assets—other	3			3
	Canadian government securities	Investments and other assets—other	101			131
	Bankers acceptances	Investments and other assets—other	—			10
	Total held-to-maturity securities		$	172		$	213
	All of our HTM securities are restricted funds pursuant to certain M&N Canada and Express-Platte debt agreements. The funds restricted for M&N Canada, plus future cash from operations that would otherwise be available for distribution to the partners of M&N Canada, are required to be placed in escrow until the balance in escrow is sufficient to fund all future debt service on the M&N Canada 6.90% senior secured notes. There are sufficient funds held in escrow to fund all future debt service on these M&N Canada notes as of December 31, 2014.
	At December 31, 2014, 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 December 31, 2014 or 2013.
	Other Restricted Funds. In addition to the portions of the AFS and HTM securities that were restricted funds as described above, we had other restricted funds totaling $13 million at December 31, 2014 and $19 million at December 31, 2013 classified as Current Assets—Other. These restricted funds are related to additional amounts for the M&N Canada debt service requirements and insurance. We also had other restricted funds totaling $6 million at December 31, 2014 classified as Investments and Other Assets—Other. These restricted funds are related to funds held and collected from customers for M&N Canada pipeline abandonment in accordance with the NEB’s regulatory requirements.
	Changes in restricted balances are presented within Cash Flows from Investing Activities on our Consolidated Statements of Cash Flows.
	Interest income. Interest income totaled $4 million in 2014, and $6 million in both 2013 and 2012, and is included in Other Income and Expenses, Net on the Consolidated Statements of Operations.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment
		Estimated		December 31,
		Useful Life		2014			2013
		(years)		(in millions)
	Plant
	Natural gas transmission	15–100		$	15,001		$	14,491
	Natural gas distribution	25–60		2,971			3,076
	Gathering and processing facilities	25–40		4,765			4,848
	Natural gas storage	10–122		2,162			2,113
	Crude oil transportation and storage	30–75		1,169			1,243
	Land rights and rights of way	21–122		568			562
	Other buildings and improvements	10–50		132			134
	Equipment	3–40		343			341
	Vehicles	5–20		114			115
	Land	—		150			128
	Construction in process	—		1,113			630
	Software	4–10		387			438
	Other	5–82		336			337
	Total property, plant and equipment			29,211			28,456
	Total accumulated depreciation			(6,543		)	(6,258		)
	Total accumulated amortization			(361		)	(369		)
	Total net property, plant and equipment			$	22,307		$	21,829
	We had no material capital leases at December 31, 2014 or 2013.
	Almost 85% of our property, plant and equipment is regulated with estimated useful lives based on rates approved by the applicable regulatory authorities in the United States and Canada: the FERC, the NEB and the OEB. Composite weighted-average depreciation rates were 2.82% for 2014, 2.96% for 2013 and 3.14% for 2012.
	Amortization expense of intangible assets totaled $74 million in 2014, $65 million in 2013 and $81 million in 2012. Estimated amortization expense for the next five years follows:
		Estimated
		Amortization
		Expense
		(in millions)
	2015	$	80
	2016		68
	2017		57
	2018		44
	2019		34

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations
	Our ARO’s relate mostly to the retirement of certain gathering pipelines and processing facilities, obligations related to right-of-way agreements and contractual leases for land use. However, we have determined that a significant portion of our assets have an indeterminate life, and as such, the fair values of those associated retirement obligations are not reasonably estimable. These assets include onshore and some offshore pipelines, and certain processing plants and distribution facilities, whose retirement dates will depend mostly on the various natural gas supply sources that connect to our systems and the ongoing demand for natural gas usage in the markets we serve. We expect these supply sources and market demands to continue for the foreseeable future, therefore we are unable to estimate retirement dates that would result in asset retirement obligations.
	ARO’s are adjusted each period for liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows. In 2014, Western Canada Transmission & Processing revised the estimated future cash flow assumptions for its ARO liabilities relating to asbestos abatement at its processing plants which resulted in an increase to ARO liabilities by $44 million. In 2013, Union Gas, which is a rate-regulated entity, reevaluated its estimated future cash flow assumptions for its ARO liabilities in connection with its 2013 rate filing with the OEB. This resulted in an increase in its estimates of expected future costs of abandoning distribution service pipelines by $172 million.
	Reconciliation of Changes in Asset Retirement Obligation Liabilities
		2014			2013
		(in millions)
	Balance at beginning of year	$	350		$	188
	Accretion expense	16			9
	Revisions in estimated cash flows (a)	72			172
	Foreign currency exchange impact	(28		)	(12		)
	Liabilities settled	(10		)	(7		)
	Balance at end of year (b)	$	400		$	350
	__________
	(a) Reflects revised assumptions regarding ARO Liabilities relating to asbestos abatement at Western Canada Transmission & Processing in 2014 and expected future costs of abandonments at Union Gas in 2013.
	(b)	Amounts included in Deferred Credits and Other Liabilities in the Consolidated Balance Sheets.

Debt_and_Credit_Facilities

Debt and Credit Facilities	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt and Credit Facilities	Debt and Credit Facilities
	Summary of Debt and Related Terms	December 31,
		2014				2013
	Spectra Energy Capital, LLC	(in millions)
	5.50% senior unsecured notes due March 2014	$	—			$	149
	5.67% senior unsecured notes due August 2014	—				408
	6.20% senior unsecured notes due April 2018	500				500
	6.75% senior unsecured notes due July 2018	150				150
	Variable-rate senior unsecured term loan due November 2018	300				—
	8.00% senior unsecured notes due October 2019	500				500
	5.65% senior unsecured notes due March 2020	300				300
	3.30% senior unsecured notes due March 2023	650				650
	6.75% senior unsecured notes due February 2032	240				240
	7.50% senior unsecured notes due September 2038	250				250
	Total Spectra Energy Capital, LLC Debt	2,890				3,147
	SEP
	SEP 2.95% senior unsecured notes due June 2016	250				250
	SEP 2.95% senior unsecured notes due September 2018	500				500
	SEP Variable-rate senior unsecured term loan due November 2018	400				400
	SEP 4.60% senior unsecured notes due June 2021	250				250
	SEP 4.75% senior unsecured notes due March 2024	1,000				1,000
	SEP 5.95% senior unsecured notes due September 2043	400				400
	Texas Eastern 6.00% senior unsecured notes due September 2017	400				400
	Texas Eastern 4.13% senior unsecured notes due December 2020	300				300
	Texas Eastern 2.80% senior unsecured notes due October 2022	500				500
	Texas Eastern 7.00% senior unsecured notes due July 2032	450				450
	Algonquin 3.51% senior notes due July 2024	350				350
	East Tennessee Natural Gas, LLC 3.10% senior notes due December 2024	200				200
	M&N U.S. 7.50% senior notes due May 2014	—				411
	Express-Platte 6.09% senior secured notes due January 2020	110				110
	Express-Platte 7.39% subordinated secured notes due 2014 to 2019	74				104
	Total SEP Debt	5,184				5,625
	Westcoast
	8.50% debentures due November 2015	108				118
	3.28% medium-term notes due January 2016	215				235
	8.50% debentures due September 2018	129				141
	5.60% medium-term notes due January 2019	258				282
	9.90% debentures due January 2020	86				94
	4.57% medium-term notes due July 2020	215				235
	3.88% medium-term notes due October 2021	129				142
	3.12% medium-term notes due December 2022	215				235
	3.43% medium-term notes due September 2024	301				—
	8.85% debentures due July 2025	129				142
	8.80% medium-term notes due November 2025	22				24
	7.30% debentures due December 2026	108				118
	6.75% medium-term notes due December 2027	129				141
	7.15% medium-term notes due March 2031	172				188
	4.79% medium-term notes due October 2041	129				141
	M&N Canada 6.90% senior secured notes due 2014 to 2019	112				147
	M&N Canada 4.34% senior secured notes due 2014 to 2019	83				120
	Other	2				2
	Total Westcoast Debt	$	2,542			$	2,505
		December 31,
		2014				2013
	Union Gas	(in millions)
	7.90% debentures due February 2014	$	—			$	141
	11.50% debentures due August 2015	129				141
	4.64% medium-term notes due June 2016	172				188
	9.70% debentures due November 2017	108				118
	5.35% medium-term notes due April 2018	172				188
	8.75% debentures due August 2018	108				118
	8.65% senior debentures due October 2018	64				72
	2.76% medium-term notes due June 2021	172				—
	4.85% medium-term notes due April 2022	108				118
3.79% medium-term notes due July 2023	215				235
8.65% debentures due November 2025	108				118
5.46% medium-term notes due September 2036	142				155
6.05% medium-term notes due September 2038	258				282
5.20% medium-term notes due July 2040	215				235
4.88% medium-term notes due June 2041	258				282
4.20% medium-term notes due June 2044	215				—
Total Union Gas Debt	2,444				2,391
Total
Long-term debt principal (including current maturities)	13,060				13,668
Change in fair value of debt hedged	17				17
Unamortized debt discount, net	(12		)		(12		)
Other unamortized items	7				12
Total other non-principal amounts	12				17
Commercial paper (a)	1,583				1,032
Capital Leases	24				—
Total debt (including capital lease obligations) (b)	14,679				14,717
Current maturities of long-term debt	(327		)		(1,197		)
Commercial paper (c)	(1,583		)		(1,032		)
Total long-term debt (including capital lease obligations)	$	12,769			$	12,488
______
(a)	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
(b)	As of December 31, 2014 and 2013, respectively, $5,264 million and $5,248 million of debt was denominated in Canadian dollars.
(c)	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.
Secured Debt. Secured debt, totaling $379 million as of December 31, 2014, includes project financings for M&N Canada and Express-Platte. Ownership interests in M&N Canada and certain of its accounts, revenues, business contracts and other assets are pledged as collateral. Express-Platte notes payable are secured by the assignment of the Express-Platte transportation receivables and by the Canadian portion of the Express-Platte pipeline system assets.
Floating Rate Debt. Debt included approximately $2,283 million of floating-rate debt as of December 31, 2014 and $1,432 million as of December 31, 2013. The weighted average interest rate of borrowings outstanding that contained floating rates was 0.8% at both December 31, 2014 and 2013.
Annual Maturities	31-Dec-14
	(in millions)
2015	$	327
2016	713
2017	563
2018	2,353
2019	787
Thereafter	8,353
Total long-term debt, including current maturities (a)	$	13,096
______
(a)	Excludes commercial paper of $1,583 million. Includes capital leases of $24 million and other non-principal amounts of $12 million.
We have the ability under certain debt facilities to call and repay the obligations prior to scheduled maturities. Therefore, the actual timing of future cash repayments could be materially different than presented above.
Available Credit Facilities and Restrictive Debt Covenants
	Expiration		Total				Commercial Paper Outstanding at December 31, 2014		Available
	Date		Credit						Credit
			Facilities						Facilities
			Capacity						Capacity
			(in millions)
Spectra Energy Capital, LLC (a)	2019		$	1,000			$	398	$	602
SEP (b)	2019		2,000				907		1,093
Westcoast (c)	2019		344				46		298
Union Gas (d)	2019		430				232		198
Total			$	3,774			$	1,583	$	2,191
______
(a)	Revolving credit facility contains a covenant requiring the Spectra Energy Corp consolidated debt-to-total capitalization ratio, as defined in the agreement, to not exceed 65%. Per the terms of the agreement, collateralized debt is excluded from the calculation of the ratio. This ratio was 58% at December 31, 2014.
(b)	Revolving credit facility contains a covenant that requires SEP to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the agreement, of 5.0 to 1 or less. As of December 31, 2014, this ratio was 3.7 to 1.
(c)	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 400 million Canadian dollars and contains a covenant that requires the Westcoast non-consolidated debt-to-total capitalization ratio to not exceed 75%. The ratio was 35% at December 31, 2014.
(d)	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 500 million Canadian dollars and contains a covenant that requires the Union Gas debt-to-total capitalization ratio to not exceed 75% and a provision which requires Union Gas to repay all borrowings under the facility for a period of two days during the second quarter of each year. The ratio was 68% at December 31, 2014.
On December 10, 2014, we amended the Westcoast and Union Gas revolving credit agreements. The Westcoast revolving credit facility was increased to 400 million Canadian dollars, and the Union Gas revolving credit facility was increased to 500 million Canadian dollars. Both facilities expire in December 2019.
On December 11, 2014, we amended the Spectra Energy Capital, LLC (Spectra Capital) and SEP revolving credit agreements. The expiration date of both credit facilities was extended one year, with both facilities expiring in December 2019.
The issuances of commercial paper, letters of credit and revolving borrowings reduce the amounts available under the credit facilities. As of December 31, 2014, there were no letters of credit issued or revolving borrowings outstanding under the credit facilities.
Our credit agreements contain various covenants, including the maintenance of certain financial ratios. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of December 31, 2014, we were in compliance with those covenants. In addition, our credit agreements allow for acceleration of payments or termination of the agreements due to nonpayment, or in some cases, due to the acceleration of other significant indebtedness of the borrower or some of its subsidiaries. Our debt and credit agreements do not contain provisions that trigger an acceleration of indebtedness based solely on the occurrence of a material adverse change in our financial condition or results of operations.
As noted above, the terms of our Spectra Capital credit agreements require our consolidated debt-to-total capitalization ratio, as defined in the agreement, to be 65% or lower. Per the terms of the agreements, collateralized debt is excluded from the calculation of the ratio. This ratio was 58% at December 31, 2014. Approximately $7.8 billion of our equity (net assets) was considered restricted at December 31, 2014, representing the minimum amount of equity required to maintain the 65% consolidated debt-to-total capitalization ratio.

Preferred_Stock_of_Subsidiarie

Preferred Stock of Subsidiaries	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Preferred Stock of Subsidiaries	Preferred Stock of Subsidiaries
	Westcoast and Union Gas have outstanding preferred shares that are generally not redeemable prior to specified redemption dates. On or after those dates, the shares may be redeemed, in whole or in part, for cash at the option of Westcoast and Union Gas, as applicable. The shares are not subject to any sinking fund or mandatory redemption and are not convertible into any other securities. As redemption of the shares is not solely within our control, we have classified the preferred stock of subsidiaries as temporary equity on our Consolidated Balance Sheets. Dividends are cumulative and payable quarterly, and are included in Net Income — Noncontrolling Interests in the Consolidated Statements of Operations. All outstanding preferred shares are redeemable at the option of Westcoast and Union Gas, as applicable.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements
	The following presents, for each of the fair value hierarchy levels, assets and liabilities that are measured and recorded at fair value on a recurring basis:
	Description		31-Dec-14
		Consolidated Balance Sheet Caption	Total			Level 1			Level 2			Level 3
			(in millions)
	Corporate debt securities	Cash and cash equivalents	$	85		$	—		$	85		$	—
	Corporate debt securities	Current assets — other	3			—			3			—
	Commodity derivatives	Current assets — other	57			—			—			57
	Interest rate swaps	Current assets — other	2			—			2			—
	Commodity derivatives	Investments and other assets — other	21			—			—			21
	Corporate debt securities	Investments and other assets — other	20			—			20			—
	Interest rate swaps	Investments and other assets — other	22			—			22			—
	Money market funds	Investments and other assets — other	1			1			—			—
	Total Assets		$	211		$	1		$	132		$	78
	Description	Consolidated Balance Sheet Caption	31-Dec-13
			Total			Level 1			Level 2			Level 3
			(in millions)
	Corporate debt securities	Cash and cash equivalents	$	49		$	—		$	49		$	—
	Corporate debt securities	Current assets — other	7			—			7			—
	Interest rate swaps	Current assets — other	8			—			8			—
	Corporate debt securities	Investments and other assets — other	11			—			11			—
	Interest rate swaps	Investments and other assets — other	15			—			15			—
	Money market funds	Investments and other assets — other	1			1			—			—
	Total Assets		$	91		$	1		$	90		$	—
	Natural gas purchase contracts	Deferred credits and other liabilities —     regulatory and other	$	3		$	—		$	—		$	3
	Interest rate swaps	Deferred credits and other liabilities —     regulatory and other	6			—			6			—
	Total Liabilities		$	9		$	—		$	6		$	3
	The following presents changes in Level 3 assets and liabilities that are measured at fair value on a recurring basis using significant unobservable inputs:
		2014			2013
		(in millions)
	Derivative assets (liabilities)
	Fair value, beginning of period	$	(3	)	$	(9	)
	Total gains (losses):
	Included in earnings	91			(3		)
	Included in other comprehensive income	5			8
	Settlements	(15		)	1
	Fair value, end of period	$	78		$	(3	)
	Total gains (losses) for the period included in earnings (or changes in net assets) attributable to the change in unrealized gains or losses relating to assets and liabilities held at the end of the period	$	56		$	(2	)
	Level 1
	Level 1 valuations represent quoted unadjusted prices for identical instruments in active markets.
	Level 2 Valuation Techniques
	Fair values of our financial instruments that are actively traded in the secondary market, including our long-term debt, are determined based on market-based prices. These valuations may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.
	For interest rate swaps, we utilize data obtained from a third-party source for the determination of fair value. Both the future cash flows for the fixed-leg and floating-leg of our swaps are discounted to present value. In addition, credit default swap rates are used to develop the adjustment for credit risk embedded in our positions. We believe that since some of the inputs and assumptions for the calculations of fair value are derived from observable market data, a Level 2 classification is appropriate.
	Level 3 Valuation Techniques
	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.
	The derivative financial instruments reported in Level 3 at December 31, 2014 primarily consist of NGL revenue swap contracts related to the Empress assets in Western Canada Transmission & Processing. As of December 31, 2014, we reported certain of our natural gas basis swaps at fair value using Level 3 inputs due to such derivatives not having observable market prices for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations whose contract length extends into unobservable periods.
	The fair value of these natural gas basis swaps is determined using a discounted cash flow valuation technique based on a forward commodity basis curve. For these derivatives, the primary input to the valuation model is the forward commodity basis curve, which is based on observable or public data sources and extrapolated when observable prices are not available.
	The significant unobservable inputs used in the fair value measurements of our Level 3 derivatives are the forward natural gas basis curves, for which a significant portion of the derivative’s term is beyond available forward pricing. At December 31, 2014, a 10¢ per gallon movement in underlying forward NGL prices would affect the estimated fair value of our NGL derivatives by $16 million. This calculated amount does not take into account any other changes to the fair value measurement calculation.
	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.
		December 31,
		2014						2013
		Book			Approximate			Book			Approximate
		Value			Fair Value			Value			Fair Value
		(in millions)
	Note receivable, noncurrent (a)	$	71		$	71		$	71		$	71
	Long-term debt, including current maturities (b)	13,060			14,446			13,668			14,701
	__________
	(a)	Included within Investments in and Loans to Unconsolidated Affiliates.
	(b)	Excludes capital leases, 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, notes receivable-noncurrent, accounts payable and commercial paper are not materially different from their carrying amounts because of the short-term nature of these instruments or because the stated rates approximate market rates.
	During the 2014 and 2013 periods, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

Risk_Management_and_Hedging_Ac

Risk Management and Hedging Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management and Hedging Activities	Risk Management and Hedging Activities
	We are exposed to the impact of market fluctuations in the prices of NGLs and natural gas purchased as a result of our investment in DCP Midstream, and the ownership of the NGL marketing operations in western Canada and processing operations associated with our U.S. pipeline assets. Exposure to interest rate risk exists as a result of the issuance of variable and fixed-rate debt and commercial paper. We are exposed to foreign currency risk from our Canadian operations. We employ established policies and procedures to manage our risks associated with these market fluctuations, which may include the use of derivatives, mostly around interest rate and commodity exposures.
	DCP Midstream manages their direct exposure to market prices separate from Spectra Energy, and utilizes various risk management strategies, including the use of commodity derivatives.
	Derivative Portfolio Carrying Value as of December 31, 2014
		Maturities			Maturities			Maturities			Maturities		Total
		in 2015			in 2016			in 2017			in 2018		Carrying
											and		Value
											Thereafter
		(in millions)
	Derivatives designated as hedging instruments
	Interest rate swaps	$	—		$	—		$	2		$	20	$	22
	Total derivatives designated as hedging instruments	—			—			2			20		22
	Derivatives not designated as hedging instruments
	Commodity derivatives	57			19			2			—		78
	Interest rate swaps	2			—			—			—		2
	Total derivatives not designated as hedging instruments	59			19			2			—		80
	Total derivative instruments	$	59		$	19		$	4		$	20	$	102
	These amounts represent the combination of amounts presented as assets for non-cash gains on mark-to-market and hedging transactions on our Consolidated Balance Sheet and do not include any derivative positions of DCP Midstream. See Note 18 for information regarding the presentation of these derivative positions on our Consolidated Balance Sheets.
	Commodity Derivatives. Our NGL marketing operations are exposed to market fluctuations in the prices of natural gas and NGLs related to natural gas processing and marketing activities. We closely monitor the potential effects of commodity price changes and may choose to enter into contracts to protect margins for a portion of future sales and fuel expenses by using financial commodity instruments, such as swaps, forward contracts and options.
	Effective January 2014, we implemented a commodity price risk management program at Western Canada Transmission & Processing’s Empress NGL business and elected to not apply cash flow hedge accounting.
	At December 31, 2014, we had commodity mark-to-market derivatives outstanding with a total notional amount of 163 million gallons. The longest dated commodity derivative contract we currently have expires in 2017.
	Information about our commodity derivatives that had netting or rights of offset arrangements are as follows:
		31-Dec-14
		Gross			Gross			Net Amount Presented in the Condensed Consolidated Balance Sheets
		Amounts			Amounts
					Offset
	Description	(in millions)
	Assets	$	169		$	91		$	78
	Liabilities	91			91			—
	Substantially all of our commodity derivative agreements outstanding at December 31, 2014 have provisions that require collateral to be posted in the amount of the net liability position if one of our credit ratings falls below investment grade.
	Information regarding the impacts of commodity derivatives on our Consolidated Statements of Operations is as follows:
	Derivatives		Consolidated Statement of Operations Caption	2014			2013			2012
				(in millions)
	Commodity derivatives		Sales of natural gas liquids	$	93		$	—		$	—
	Interest Rate Swaps. Changes in interest rates expose us to risk as a result of our issuance of variable and fixed-rate debt and commercial paper. We manage our interest rate exposure by limiting our variable-rate exposures to percentages of total debt and by monitoring the effects of market changes in interest rates. We also enter into financial derivative instruments, including, but not limited to, interest rate swaps and rate lock agreements to manage and mitigate interest rate risk exposure.
	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 included in Interest Expense on the Consolidated Statements of Operations. There were no significant amounts of gains or losses, either effective or ineffective, recognized in net income or other comprehensive income in 2014, 2013 or 2012.
	At December 31, 2014, we had “pay floating — receive fixed” interest rate swaps outstanding with a total notional amount of $1,208 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:
		31-Dec-14									31-Dec-13
		Gross Amounts			Amounts Not			Net			Gross Amounts		Amounts Not		Net
		Presented in			Offset in the			Amount			Presented in		Offset in the		Amount
		the Consolidated			Consolidated						the Consolidated		Consolidated
		Balance Sheets			Balance Sheets						Balance Sheets		Balance Sheets
	Description	(in millions)
	Assets	$	24		$	—		$	24		$	23	$	3	$	20
	Liabilities	—			—			—			6		3		3
	Foreign Currency Risk. We are exposed to foreign currency risk from investments and operations in Canada. To mitigate risks associated with foreign currency fluctuations, contracts may be denominated in or indexed to the U.S. dollar and/or local inflation rates, or investments may be naturally hedged through debt denominated or issued in the foreign currency. To monitor our currency exchange rate risks, we use sensitivity analysis, which measures the effect of devaluation of the Canadian dollar.
	Credit Risk. Our principal customers for natural gas transmission and crude oil transportation, storage and gathering and processing services are industrial end-users, marketers, exploration and production companies, local distribution companies and utilities located throughout the United States and Canada. We have concentrations of receivables from natural gas utilities and their affiliates, industrial customers and marketers throughout these regions, as well as retail distribution customers in Canada. These concentrations of customers may affect our overall credit risk in that risk factors can negatively affect the credit quality of the entire sector. Where exposed to credit risk, we analyze the customers’ financial condition prior to entering into an agreement, establish credit limits and monitor the appropriateness of those limits on an ongoing basis. We also obtain parental guarantees, cash deposits or letters of credit from customers to provide credit support, where appropriate, based on our financial analysis of the customer and the regulatory or contractual terms and conditions applicable to each contract.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	General Insurance
	We carry, either directly or through our captive insurance companies, insurance coverages consistent with companies engaged in similar commercial operations with similar type properties. Our insurance program includes (1) commercial general and excess liability insurance for liabilities to third parties for bodily injury and property damage resulting from our operations; (2) workers’ compensation liability coverage to required statutory limits; (3) automobile liability insurance for all owned, non-owned and hired vehicles covering liabilities to third parties for bodily injury and property damage; (4) insurance policies in support of the indemnification provisions of our by-laws; and (5) property insurance, including machinery breakdown, on an all-risk-replacement valued basis, onshore business interruption and extra expense. All coverages are subject to certain deductibles, terms and conditions common for companies with similar types of operations.
	Environmental
	We are subject to various U.S. federal, state and local laws and regulations, as well as Canadian federal and provincial laws, regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These laws and regulations can change from time to time, imposing new obligations on us.
	Like others in the energy industry, we and our affiliates are responsible for environmental remediation at various contaminated sites. These include some properties that are part of our ongoing operations, sites formerly owned or used by us, and sites owned by third parties. Remediation typically involves management of contaminated soils and may involve groundwater remediation. Managed in conjunction with relevant federal, state/provincial and local agencies, activities vary with site conditions and locations, remedial requirements, complexity and sharing of responsibility. If remediation activities involve statutory joint and several liability provisions, strict liability, or cost recovery or contribution actions, we or our affiliates could potentially be held responsible for contamination caused by other parties. In some instances, we may share liability associated with contamination with other potentially responsible parties, and may also benefit from contractual indemnities that cover some or all cleanup costs. All of these sites generally are managed in the normal course of business or affiliated operations.
	Included in Deferred Credits and Other Liabilities — Regulatory and Other on the Consolidated Balance Sheets are undiscounted liabilities related to extended environmental-related activities totaling $10 million as of December 31, 2014 and $11 million as of December 31, 2013. These liabilities represent provisions for costs associated with remediation activities at some of our current and former sites, as well as other environmental contingent liabilities.
	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 December 31, 2014 or 2013 related to litigation.
	Other Commitments and Contingencies
	See Note 21 for a discussion of guarantees and indemnifications.
	Operating Lease Commitments
	We lease assets in various areas of our operations. Consolidated rental expense for operating leases classified in Income From Continuing Operations was $38 million in 2014, 2013 and 2012, which is included in Operating, Maintenance and Other on the Consolidated Statements of Operations. The following is a summary of future minimum lease payments under operating leases which at inception had noncancelable terms of more than one year. We had no material capital lease commitments at December 31, 2014.
		Long-term
		Operating
		Leases
		(in millions)
	2015	$	50
	2016	44
	2017	42
	2018	36
	2019	32
	Thereafter	148
	Total future minimum lease payments	$	352

Guarantees_and_Indemnification

Guarantees and Indemnifications	12 Months Ended
	Dec. 31, 2014
Guarantees [Abstract]
Guarantees and Indemnifications	Guarantees and Indemnifications
	We have various financial guarantees and indemnifications which are issued in the normal course of business. As discussed below, these contracts include financial guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. 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 Consolidated Balance Sheets. The possibility of having to perform under these guarantees and indemnifications is largely dependent upon future operations of various subsidiaries, investees and other third parties, or the occurrence of certain future events.
	We have issued performance guarantees to customers and other third parties that guarantee the payment and performance of other parties, including certain non-100%-owned entities. In connection with our spin-off from Duke Energy in 2007, certain guarantees that were previously issued by us were assigned to, or replaced by, Duke Energy as guarantor in 2006. For any remaining guarantees of other Duke Energy obligations, Duke Energy has indemnified us against any losses incurred under these guarantee arrangements. The maximum potential amount of future payments we could have been required to make under these performance guarantees as of December 31, 2014 was approximately $406 million, which has been indemnified by Duke Energy as discussed above. One of these outstanding performance guarantees, which has a maximum potential amount of future payment of $201 million, expires in 2028. The remaining guarantees have no contractual expirations.
	We have also issued joint and several guarantees to some of the Duke/Fluor Daniel (D/FD) project owners, guaranteeing the performance of D/FD under its engineering, procurement and construction contracts and other contractual commitments in place at the time of our spin-off from Duke Energy. D/FD is one of the entities transferred to Duke Energy in connection with our spin-off. Substantially all of these guarantees have no contractual expiration and no stated maximum amount of future payments that we could be required to make. Fluor Enterprises Inc., as 50% owner in D/FD, issued similar joint and several guarantees to the same D/FD project owners.
	Westcoast, a 100%-owned subsidiary, has issued performance guarantees to third parties guaranteeing the performance of unconsolidated entities, such as equity method investments, and of entities previously sold by Westcoast to third parties. Those guarantees require Westcoast to make payment to the guaranteed third party upon the failure of such unconsolidated or sold entity to make payment under some of its contractual obligations, such as debt agreements, purchase contracts and leases. Certain guarantees that were previously issued by Westcoast for obligations of entities that remained a part of Duke Energy are considered guarantees of third party performance; however, Duke Energy has indemnified us against any losses incurred under these guarantee arrangements.
	We have entered into various indemnification agreements related to purchase and sale agreements and other types of contractual agreements with vendors and other third parties. These agreements typically cover environmental, litigation and other matters, as well as breaches of representations, warranties and covenants. Typically, claims may be made by third parties for various periods of time depending on the nature of the claim. Our potential exposure under these indemnification agreements can range from a specified amount, such as the purchase price, to an unlimited dollar amount, depending on the nature of the claim and the particular transaction. We are unable to estimate the total potential amount of future payments under these indemnification agreements due to several factors, such as the unlimited exposure under certain guarantees.
	As of December 31, 2014, the amounts recorded for the guarantees and indemnifications described above are not material, both individually and in the aggregate.

Common_Stock_Issuance

Common Stock Issuance	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Common Stock Issuance	Common Stock Issuance
	In 2012, we issued 14.7 million shares of our common stock and received net proceeds of $382 million to fund acquisitions and capital expenditures and for other general corporate purposes.

Effects_of_Changes_in_Noncontr

Effects of Changes in Noncontrolling Interests Ownership	12 Months Ended
	Dec. 31, 2014
Noncontrolling Interest [Abstract]
Effects of Changes in Noncontrolling Interests Ownership	Effects of Changes in Noncontrolling Interests Ownership
	The following table presents the effects of changes in our ownership interests in non-100%-owned consolidated subsidiaries:
		2014		2013		2012
		(in millions)
	Net income — controlling interests	$	1,082	$	1,038	$	940
	Increase in additional paid-in capital resulting from issuances of SEP units (a)	49		42		26
	Total net income — controlling interests and changes in equity — controlling interests	$	1,131	$	1,080	$	966
	________________
	(a)	See Note 2 for further discussion.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	Stock-Based Compensation
	The Spectra Energy Corp 2007 Long-Term Incentive Plan (the 2007 LTIP), as amended and restated, provides for the granting of stock options, restricted and unrestricted stock awards and units, and other equity-based awards, to employees and other key individuals who perform services for us. A maximum of 40 million shares of common stock may be awarded under the 2007 LTIP.
	Restricted, performance and phantom awards granted under the 2007 LTIP typically become 100% vested on the three-year anniversary of the grant date. Equity-classified and liability-classified stock-based compensation cost is measured at the grant date based on the fair value of the award. Liability-classified stock-based compensation cost is re-measured at each reporting period until settlement. Related compensation expense is recognized over the requisite service period, which generally begins on the date the award is granted through the earlier of the date the award becomes vested, the date the employee becomes retirement-eligible, or the date the market or performance condition is met.
	Options granted under the 2007 LTIP are issued with exercise prices equal to the fair market value of our common stock on the grant date, have ten-year terms and generally vest over a three-year term. Compensation expense related to stock options is recognized over the requisite service period. The requisite service period for stock options is the same as the vesting period, with the exception of retirement eligible employees, who have shorter requisite service periods ending when the employees become retirement eligible. We issue new shares upon exercising or vesting of share-based awards. The Black-Scholes option-pricing model is used to estimate the fair value of options at grant date. All outstanding stock options are fully vested, and as a result, we do not expect to recognize future compensation costs related to stock options.
	We recorded pre-tax stock-based compensation expense in continuing operations as follows, the components of which are described further below:
		2014				2013			2012
		(in millions)
	Phantom awards	$	14			$	13		$	12
	Performance awards	13				33			17
	Total	$	27			$	46		$	29
	The tax benefit in Income From Continuing Operations associated with the recorded stock-based compensation expense was $7 million in 2014 and $8 million in both 2013 and 2012. We recognized tax benefits from stock-based compensation cost of approximately $3 million in 2014, $5 million in 2013 and $16 million in 2012 in Additional Paid-in Capital.
	Stock Awards Activity
		Performance						Phantom Stock
		Awards						Awards
		Units			Weighted			Units			Weighted
					Average						Average
					Grant						Grant
					Date Fair						Date Fair
					Value						Value
		(thousands)						(thousands)
	Outstanding at December 31, 2013	1,936			$	38		1,302			$	29
	Granted	557			46			454			38
	Vested	(601	)		33			(431	)		26
	Forfeited	(117	)		38			(44	)		33
	Outstanding at December 31, 2014	1,775			35			1,281			33
	Awards expected to vest	1,709			35			1,229			33
	Performance Awards
	Under the 2007 LTIP, we can also grant stock-based performance awards. The performance awards generally vest over three years at the earliest, if performance metrics are met. The liability-classified awards will be settled in cash at vesting. We granted 557,100 equity-classified awards during 2014, 356,600 during 2013 and 306,800 during 2012, with fair values of $26 million in 2014 and $13 million in both 2013 and 2012. We did not grant liability-classified awards during 2014; however, we granted 343,700 during 2013 and 306,800 during 2012, with fair values of $13 million in 2013 and $5 million in 2012. Of the unvested and outstanding performance awards granted, 1,761,967 awards contain market conditions based on the total shareholder return of Spectra Energy common stock relative to a pre-defined peer group, and 12,900 awards contain performance conditions based on EBITDA performance of one subsidiary company. The equity-classified and liability-classified awards with market conditions are valued using the Monte Carlo valuation method. The liability-classified awards are remeasured at each reporting period until settlement.
	Weighted-Average Assumptions for Stock-Based Performance Awards
		2014		2013		2012
	Risk-free rate of return	0.70%		0.40%		0.40%
	Expected life	3 years		3 years		3 years
	Expected volatility—Spectra Energy	20%		21%		25%
	Expected volatility—peer group	14%–32%		13%–33%		16%–42%
	Market index (a)	N/A		16%		20%
	__________
	(a) Beginning in 2014, the valuation model was refined to use an alternate analytical approach to project future stock prices in order to improve consistency and efficiency. The improved approach does not require the use of a market index assumption to determine the future stock price used in the valuation model. As such, the volatility of the market index assumption will not be presented going forward. Based on our assessment, it was determined that this refinement did not have a significant impact on the fair value of the shares for all periods presented.
	The risk-free rate of return was determined based on a yield of three-year U.S. Treasury bonds on the grant date. The expected volatility was established based on historical volatility over three years using daily stock price observations. A shorter period was used if three years of data was not available. Because the award payout includes dividend equivalents, no dividend yield assumption is required.
	The total fair value of the shares vested was $20 million in 2014, $19 million in 2013 and $12 million in 2012. As of December 31, 2014, we expect to recognize $26 million of future compensation cost related to outstanding performance awards over a weighted-average period of less than one year.
	Phantom Awards
	Under the 2007 LTIP, we can also grant stock-based phantom awards. The phantom awards generally vest over three years. The liability-classified awards will be settled in cash at vesting. We awarded 101,500 equity-classified awards to our employees in 2014, 474,500 in 2013 and 440,200 in 2012, with fair values of $4 million in 2014, $14 million in both 2013 and 2012. We awarded 353,000 liability-classified awards to our employees in 2014, with a fair value of $13 million. The liability-classified awards are remeasured at each reporting period until settlement.
	The total fair value of the shares vested was $11 million in 2014, $14 million in 2013 and $11 million in 2012. As of December 31, 2014, we expect to recognize $18 million of future compensation cost related to phantom stock awards over a weighted-average period of less than two years.
	Stock Option Activity
		Options			Weighted-			Weighted-		Aggregate
					Average			Average		Intrinsic
					Exercise			Remaining		Value
					Price			Life
		(in thousands)						(in years)		(in millions)
	Outstanding at December 31, 2013	1,532			$	25		2.9		$	16
	Exercised	(430	)		25
	Forfeited or expired	—			—
	Outstanding at December 31, 2014	1,102			25			2		12
	Exercisable at December 31, 2014	1,102			25			2		12
	We did not award any non-qualified stock options to employees during 2014, 2013 or 2012.
	The total intrinsic value of options exercised was $6 million in 2014, $21 million in 2013 and $11 million in 2012. Cash received by us from options exercised was $11 million in 2014, $43 million in 2013 and $17 million in 2012. All stock options were fully vested as of December 31, 2011, and as a result, we do not expect to recognize future compensation costs related to stock options.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Employee Benefit Plans
	Retirement Plans. We have a qualified non-contributory defined benefit (DB) retirement plan for U.S. employees (U.S. Qualified Pension Plan). This plan covers U.S. employees using a cash balance formula. Under a cash balance formula, a plan participant accumulates a retirement benefit consisting of pay credits that are based upon a percentage (which may vary with age and years of service) of current eligible earnings and current interest credits.
	We also maintain non-qualified, non-contributory, unfunded defined benefit plans (U.S. Non-Qualified Pension Plans) which cover certain current and former U.S. executives. The U.S. Non-Qualified Pension Plans have no plan assets. There are other non-qualified plans such as savings and deferred compensation plans which cover certain current and former U.S. executives. Pursuant to trust agreements, Spectra Energy has set aside funds for certain of the above non-qualified plans in several trusts. Although these funds are restrictive in nature, they remain a component of our general assets and are subject to the claims of creditors. These trust funds totaling $17 million as of December 31, 2014 and $18 million as of December 31, 2013, invested in money market funds and valued using a Level 1 hierarchy level, are considered AFS securities and are classified as Investments and Other Assets-Other on the Consolidated Balance Sheets.
	In addition, our Westcoast subsidiary maintains qualified and non-qualified, contributory and non-contributory (Canadian Qualified Pension Plan) and (Canadian Non-Qualified Pension Plan) DB and defined contribution (Canadian DC) retirement plans covering substantially all employees of our Canadian operations. The DB plans provide retirement benefits based on each plan participant’s years of service and final average earnings. Under the Canadian DC plan, company contributions are determined according to the terms of the plan and based on each plan participant’s age, years of service and current eligible earnings. We also provide non-qualified DB supplemental pensions to all employees who retire under a DB qualified pension plan and whose pension is limited by the maximum pension limits under the Income Tax Act (Canada). We report our Canadian benefit plans separate from the U.S. plans due to differences in actuarial assumptions.
	Our policy is to fund our retirement plans, where applicable, on an actuarial basis to provide assets sufficient to meet benefits to be paid to plan participants or as required by legislation or plan terms. We made contributions of $21 million to our U.S. Qualified and Non-Qualified Pension Plans in 2014, $22 million in 2013 and $26 million in 2012. We made total contributions to our Canadian Qualified and Non-Qualified Pension Plans of $36 million in 2014, $80 million in 2013 and $87 million in 2012. Contributions of $9 million in 2014, 2013 and 2012 were made to our Canadian DC plan. We anticipate that in 2015 we will make total contributions of approximately $22 million to the U.S. Qualified and Non-Qualified Pension Plans, approximately $30 million to the Canadian Qualified and Non-Qualified Pension Plans and approximately $10 million to the Canadian DC Plan.
	Actuarial gains and losses are amortized over the average remaining service period of active employees. The average remaining service period of active employees covered by the U.S. Qualified and Non-Qualified Pension Plans is 10 years. The average remaining service periods of active employees covered by the Canadian Qualified and Non-Qualified Pension Plans is 10 years. We determine the market-related value of plan assets using a calculated value that recognizes changes in fair value of the plan assets over five years for the U.S. plans and over three years for the Canadian plans.
	Qualified and Non-Qualified Pension Plans
	Change in Projected Benefit Obligation and Change in Fair Value of Plan Assets
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Change in Projected Benefit Obligation
	Projected benefit obligation, beginning of period	$	575			$	610			$	1,131		$	1,262
	Transfers in	—				—				—			6
	Service cost	19				19				25			33
	Interest cost	24				21				52			50
	Actuarial loss (gain)	13				(36		)		143			(92		)
	Participant contributions	—				—				5			5
	Benefits paid	(45		)		(39		)		(49		)	(51		)
	Foreign currency translation effect	—				—				(105		)	(82		)
	Projected benefit obligation, end of period	586				575				1,202			1,131
	Change in Fair Value of Plan Assets
	Plan assets, beginning of period	531				483				1,040			961
	Transfers in	—				—				—			3
	Actual return on plan assets	44				65				115			110
	Benefits paid	(45		)		(39		)		(49		)	(51		)
	Employer contributions	21				22				36			80
	Plan participants’ contributions	—				—				5			5
	Expected non-investment expenses	—				—				(3		)	—
	Foreign currency translation effect	—				—				(94		)	(68		)
	Plan assets, end of period	551				531				1,050			1,040
	Net amount recognized	$	(35	)		$	(44	)		$	(152	)	$	(91	)
	Accumulated Benefit Obligation	$	567			$	547			$	1,123		$	1,059
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Net amount recognized
	Current Liabilities - Other	$	(2	)		$	(2	)		$	(6	)	$	(6	)
	Deferred Credits and Other Liabilities -	(33		)		(42		)		(165		)	(130		)
	Regulatory and Other
	Other Assets - Other	—				—				19			45
	Total net amount recognized	$	(35	)		$	(44	)		$	(152	)	$	(91	)
	The tables above include certain nonqualified pension plans that are unfunded. Those U.S. plans had projected benefit obligations of $22 million at both December 31, 2014 and 2013. Those Canadian plans had projected benefit obligations of $117 million at both December 31, 2014 and 2013.
	At December 31, 2014, all U.S. plans had accumulated benefit obligations in excess of plan assets. Canadian plans with accumulated benefit obligations in excess of plan assets had projected benefit obligations of $388 million, accumulated benefit obligations of $360 million and plan assets with a fair value of $239 million.
	Amounts Recognized in Accumulated Other Comprehensive Income
		U.S.								Canada
		December 31,								December 31,
		2014				2013				2014			2013
		(in millions)
	Net actuarial loss	$	141			$	145			$	345		$	275
	Prior service cost	—				1				6			7
	Total amount recognized in AOCI	$	141			$	146			$	351		$	282
	Components of Net Periodic Pension Costs
		U.S.											Canada
		2014				2013				2012			2014				2013			2012
		(in millions)
	Net Periodic Pension Cost
	Service cost benefit earned	$	19			$	19			$	17		$	29			$	33		$	30
	Interest cost on projected benefit obligation	24				21				23			52				50			50
	Expected return on plan assets	(39		)		(33		)		(33		)	(69		)		(66		)	(61		)
	Amortization of prior service cost	—				—				—			2				2			2
	Amortization of loss	13				20				15			22				35			36
	Net periodic pension cost	17				27				22			36				54			57
	Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	8				(69		)		33			93				(133		)	44
Amortization of actuarial loss	(13		)		(20		)		(15		)	(22		)		(35		)	(36		)
Amortization of prior service credit	—				—				—			(2		)		(2		)	(2		)
Total recognized in other comprehensive income	(5		)		(89		)		18			69				(170		)	6
Total Recognized in Net Periodic Pension Cost and Other Comprehensive Income	$	12			$	(62	)		$	40		$	105			$	(116	)	$	63
In 2015, approximately $10 million of actuarial losses for the U.S. plans and $27 million for the Canadian plans will be amortized from AOCI on the Consolidated Balance Sheets into net periodic pension cost, and approximately $1 million of prior service credits will be amortized from AOCI into net periodic pension costs for the Canadian plans.
Assumptions Used for Pension Benefits Accounting
	U.S.									Canada
	2014			2013			2012			2014		2013			2012
Benefit Obligations
Discount rate	4.1	%		4.31	%		3.55	%		4	%	4.81	%		4.15	%
Salary increase	4			4.61			4.61			3.25		3.25			3.25
Net Periodic Benefit Cost
Discount rate	4.31			3.55			4.17			4.81		4.15			4.3
Salary increase	4.61			4.61			4.61			3.25		3.25			3.25
Expected long-term rate of return on plan assets	8			7.4			7.4			7.4		7.1			7.1
The discount rates used to determine the benefit obligations are the rates at which the benefit obligations could be effectively settled. The discount rates for our U.S. and Canadian plans are developed from yields on available high-quality bonds in each country and reflect each plan’s expected cash flows.
The long-term rates of return for the U.S. and Canadian plan assets as of December 31, 2014 were developed using weighted-average calculations of expected returns based primarily on future expected returns across classes considering the use of active asset managers applied against the U.S. and Canadian plans’ respective targeted asset mix.
Qualified Pension Plan Assets
	U.S.									Canada
Asset Category	Target			December 31,						Target		December 31,
	Allocation			2014			2013			Allocation		2014			2013
U.S. equity securities	30	%		31	%		31	%		17	%	17	%		18	%
Canadian equity securities	—			—			—			25		25			26
Other equity securities	14			11			14			13		13			13
Fixed income securities	46			48			45			45		45			43
Other investments	10			10			10			—		—			—
Total	100	%		100	%		100	%		100	%	100	%		100	%
Pension plan assets are maintained in master trusts in both the U.S. and Canada. The investment objective of the master trusts is to achieve reasonable returns on trust assets, subject to a prudent level of portfolio risk, for the purpose of enhancing the security of benefits for plan participants. The asset allocation targets were set after considering the investment objective and the risk profile with respect to the trusts. Equities are held for their high expected return. Other equity and fixed income securities are held for diversification. Investments within asset classes are diversified to achieve broad market participation and reduce the effects of individual managers or investments. We regularly review our actual asset allocation and periodically rebalance our investments to the targeted allocation when considered appropriate.
The following table summarizes the fair values of pension plan assets recorded at each fair value hierarchy level, as determined in accordance with the valuation techniques described in Note 18:
	U.S.															Canada
	Total				Level 1				Level 2			Level 3				Total			Level 1			Level 2		Level 3
	(in millions)
31-Dec-14
Cash and cash equivalents	$	3			$	3			$	—		$	—			$	3		$	3		$	—	$	—
Fixed income securities	262				262				—			—				471			471			—		—
Equity securities	233				233				—			—				576			342			234		—
Other	53				—				—			53				—			—			—		—
Total	$	551			$	498			$	—		$	53			$	1,050		$	816		$	234	$	—
31-Dec-13
Cash and cash equivalents	$	2			$	2			$	—		$	—			$	8		$	8		$	—	$	—
Fixed income securities	240				240				—			—				442			442			—		—
Equity securities	240				240				—			—				590			428			162		—
Other	49				—				—			49				—			—			—		—
Total	$	531			$	482			$	—		$	49			$	1,040		$	878		$	162	$	—
The following presents changes in Level 3 assets that are measured at fair value on a recurring basis using significant unobservable inputs:
	U.S.								Canada
	2014				2013				2014			2013
	(in millions)
Fair value, beginning of period	$	49			$	69			$	—		$	1
Sales	—				(25		)		—			—
Settlements	—				1				—			—
Gain (loss) included in other comprehensive income	4				4				—			(1		)
Fair value, end of period	$	53			$	49			$	—		$	—
Expected Benefit Payments
	U.S.				Canada
	(in millions)
2015	$	42			$	51
2016	47				54
2017	50				57
2018	49				60
2019	53				63
2020 – 2024	235				346
Other Post-Retirement Benefit Plans
U.S. Other Post-Retirement Benefits. We provide certain health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Employees are eligible for these benefits if they have met age and service requirements at retirement, as defined in the plans.
These benefit costs are accrued over an employee’s active service period to the date of full benefits eligibility. Actuarial gains and losses are amortized over the average remaining service period of the active employees of 12 years. We determine the market-related value of the plan assets using a calculated value that recognizes changes in fair value of the plan assets over five years for the U.S. plans.
Canadian Other Post-Retirement Benefits. We provide health care and life insurance benefits for retired employees on a non-contributory basis for our Canadian operations predominantly under defined contribution plans. Employees are eligible for these benefits if they have met age and service requirements at retirement, as defined in the plans. The Canadian plans are not funded.
Other Post-Retirement Benefit Plans — Change in Projected Benefit Obligation and Fair Value of Plan Assets
	U.S.								Canada
	2014				2013				2014			2013
	(in millions)
Change in Benefit Obligation
Accumulated post-retirement benefit obligation, beginning of period	$	184			$	202			$	133		$	149
Transfers in	—				—				—			1
Service cost	1				1				4			5
Interest cost	8				7				6			6
Plan participants’ contributions	2				3				—			—
Actuarial loss (gain)	(7		)		(13		)		7			(13		)
Medicare subsidy receivable	2				2				—			—
Benefits paid	(18		)		(18		)		(4		)	(5		)
Foreign currency translation effect	—				—				(13		)	(10		)
Accumulated post-retirement benefit obligation, end of period	172				184				133			133
Change in Fair Value of Plan Assets
Plan assets, beginning of period	87				79				—			—
Actual return on plan assets	7				10				—			—
Benefits paid	(18		)		(18		)		(4		)	(5		)
Employer contributions	14				13				4			5
Plan participants’ contributions	2				3				—			—
Plan assets, end of period	92				87				—			—
Net amount recognized (a)	$	(80	)		$	(97	)		$	(133	)	$	(133	)
_______
(a)	Recognized primarily in Deferred Credits and Other Liabilities—Regulatory and Other in the Consolidated Balance Sheets.
Other Post-Retirement Benefit Plans — Amounts Recognized in Accumulated Other Comprehensive Income
	U.S.								Canada
	December 31,								December 31,
	2014				2013				2014			2013
	(in millions)
Prior service credit	$	—			$	—			$	(4	)	$	(5	)
Net actuarial loss (gain)	(4		)		6				12			6
Total amount recognized in AOCI	$	(4	)		$	6			$	8		$	1
In 2015, approximately $1 million of prior service costs will be amortized from AOCI into net periodic pension costs for the Canadian plans.
	U.S.											Canada
	2014				2013				2012			2014				2013			2012
	(in millions)
Other Post-Retirement Benefit Plans — Components of Net Periodic Benefit Cost
Service cost benefit earned	$	1			$	1			$	1		$	4			$	5		$	7
Interest cost on accumulated post-retirement benefit obligation	8				7				8			6				6			7
Expected return on plan assets	(5		)		(4		)		(5		)	—				—			—
Amortization of prior service credit	—				—				—			(1		)		(1		)	(1		)
Amortization of loss	1				2				2			—				—			2
Net periodic other post-retirement benefit cost	5				6				6			9				10			15
Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	(9		)		(18		)		6			6				(13		)	(26		)
Amortization of actuarial loss	(1		)		(2		)		(2		)	—				—			(2		)
Amortization of prior service credit	—				—				—			1				1			1
Total recognized in other comprehensive income	(10		)		(20		)		4			7				(12		)	(27		)
Total recognized in net periodic benefit cost and other comprehensive income	$	(5	)		$	(14	)		$	10		$	16			$	(2	)	$	(12	)
Other Post-Retirement Benefits Plans — Assumptions Used for Benefits Accounting
	U.S.									Canada
	2014			2013			2012			2014		2013			2012
Benefit Obligations
Discount rate	4.08	%		4.46	%		3.7	%		4	%	4.83	%		4.2	%
Salary increase	4			4.61			4.61			3.25		3.25			3.25
Net Periodic Benefit Cost
Discount rate	4.46			3.7			4.31			4.83		4.2			4.33
Salary increase	4.61			4.61			4.61			3.25		3.25			3.25
Expected return on plan assets	6.98			6.51			6.54			N/A		N/A			N/A
_________
The discount rates used to determine the post-retirement obligations are the rates at which the benefit obligations could be effectively settled. The discount rates for our U.S. and Canadian plans are developed from yields on available high-quality bonds in each country and reflect each plan’s expected cash flows.
Assumed Health Care Cost Trend Rates
	U.S.				Canada
	2014		2013		2014		2013
Health care cost trend rate assumed for next year	7.00%		7.00%		6.00%		6.50%
Rate to which the cost trend is assumed to decline	5.00%		5.00%		5.00%		5.00%
Year that the rate reaches the ultimate trend rate	2019		2019		2017		2017
Sensitivity to Changes in Assumed Health Care Cost Trend Rates
	U.S.								Canada
	1% Point				1% Point				1% Point			1% Point
	Increase				Decrease				Increase			Decrease
	(in millions)
Effect on total service and interest costs	$	—			$	—			$	1		$	(1	)
Effect on post-retirement benefit obligations	7				(6		)		9			(7		)
Other Post-Retirement Plan Assets
	U.S.
Asset Category	December 31,
	2014			2013
Equity securities	48	%		49	%
Fixed income securities	47			46
Other assets	5			5
Total	100	%		100	%
A portion of our other post-retirement plan assets is maintained within the U.S. master trust discussed under the pension plans above. We invest other post-retirement plan assets in the Spectra Energy Corp Employee Benefits Trust (VEBA I) and the Spectra Energy Corp Post-Retirement Medical Benefits Trust (VEBA II). The investment objective of the VEBAs is to achieve sufficient returns on trust assets, subject to a prudent level of portfolio risk, for the purpose of promoting the security of plan benefits for participants. The VEBA trusts are passively managed.
The asset allocation table above includes the other post-retirement benefit assets held in the master trusts, VEBA I and VEBA II.
The following table summarizes the fair values of the other post-retirement plan assets recorded at each fair value hierarchy level as determined in accordance with the valuation techniques described in Note 18:
	U.S.
	VEBA I and VEBA II Trusts															Master Trust
	Total				Level 1				Level 2			Level 3				Total			Level 1			Level 2		Level 3
	(in millions)
31-Dec-14
Fixed income securities	$	21			$	—			$	21		$	—			$	22		$	22		$	—	$	—
Equity securities	25				—				25			—				20			20			—		—
Other investments	—				—				—			—				4			—			—		4
Total	$	46			$	—			$	46		$	—			$	46		$	42		$	—	$	4
31-Dec-13
Fixed income securities	$	20			$	—			$	20		$	—			$	20		$	20		$	—	$	—
Equity securities	23				—				23			—				20			20			—		—
Other investments	—				—				—			—				4			—			—		4
Total	$	43			$	—			$	43		$	—			$	44		$	40		$	—	$	4
The following presents changes in Level 3 assets that are measured at fair value on a recurring basis using significant unobservable inputs:
	U.S.
	2014				2013
	(in millions)
Fair value, beginning of period	$	4			$	5
Sales	—				(2		)
Unrealized gain included in other comprehensive income	—				1
Fair value, end of period	$	4			$	4
Other Post-Retirement Benefit Plans-Payments and Receipts
We expect to make future benefit payments, which reflect expected future service, as appropriate. As our plans provide benefits that are actuarially equivalent to the benefits received by Medicare recipients, we expect to receive future subsidies under Medicare Part D. The following benefit payments and subsidies are expected to be paid (or received) over each of the next five years and thereafter.
	Benefit Payments								Medicare Part D Subsidy Receipts
	U.S.				Canada				U.S.
	(in millions)
2015	$	16			$	5			$	(2	)
2016	15				5				(2		)
2017	15				5				(1		)
2018	14				6				(1		)
2019	14				6				(1		)
2020 – 2024	60				33				(6		)
We anticipate making contributions in 2015 of $10 million to the U.S. plans and $5 million to the Canadian plans.
Retirement/Savings Plan
In addition to the retirement plans discussed above, we also have defined contribution employee savings plans available to both U.S. and Canadian employees. Employees may participate in a matching contribution where we match a certain percentage of before-tax employee contributions of up to 6% of eligible pay per pay period for U.S. employees and up to 5% of eligible pay per pay period for Canadian employees. We expensed pre-tax employer matching contributions of $15 million in 2014, $14 million in 2013 and $12 million in 2012 for U.S employees, and $13 million in both 2014 and 2013 and $12 million in 2012 for Canadian employees.

Consolidating_Financial_Inform

Consolidating Financial Information	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Consolidating Financial Information	Consolidating Financial Information
	Spectra Energy Corp has agreed to fully and unconditionally guarantee the payment of principal and interest under all series of notes outstanding under the Senior Indenture of Spectra Capital, a 100%-owned, consolidated subsidiary. In accordance with the Securities and Exchange Commission (SEC) rules, the following condensed consolidating financial information is presented. The information shown for Spectra Energy Corp and Spectra Capital is presented utilizing the equity method of accounting for investments in subsidiaries, as required. The non-guarantor subsidiaries column represents all consolidated subsidiaries of Spectra Capital. This information should be read in conjunction with our accompanying Consolidated Financial Statements and notes thereto.
	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2014
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,906		$	(3	)	$	5,903
	Total operating expenses	6			1			3,975			(3		)	3,979
	Operating income (loss)	(6		)	(1		)	1,931			—			1,924
	Equity in earnings of unconsolidated affiliates	—			—			361			—			361
	Equity in earnings of consolidated subsidiaries	1,054			1,651			—			(2,705		)	—
	Other income and expenses, net	(2		)	9			52			—			59
	Interest expense	—			253			426			—			679
	Earnings before income taxes	1,046			1,406			1,918			(2,705		)	1,665
	Income tax expense (benefit)	(36		)	352			66			—			382
	Net income	1,082			1,054			1,852			(2,705		)	1,283
	Net income — noncontrolling interests	—			—			201			—			201
	Net income — controlling interests	$	1,082		$	1,054		$	1,651		$	(2,705	)	$	1,082
	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2013
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,521		$	(3	)	$	5,518
	Total operating expenses	8			3			3,844			(3		)	3,852
	Operating income (loss)	(8		)	(3		)	1,677			—			1,666
	Equity in earnings of unconsolidated affiliates	—			—			445			—			445
	Equity in earnings of consolidated subsidiaries	1,015			1,649			—			(2,664		)	—
	Other income and expenses, net	1			15			108			—			124
	Interest expense	—			216			441			—			657
	Earnings before income taxes	1,008			1,445			1,789			(2,664		)	1,578
	Income tax expense (benefit)	(30		)	430			19			—			419
	Net income	1,038			1,015			1,770			(2,664		)	1,159
	Net income — noncontrolling interests	—			—			121			—			121
	Net income — controlling interests	$	1,038		$	1,015		$	1,649		$	(2,664	)	$	1,038
	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2012
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,077		$	(2	)	$	5,075
	Total operating expenses	5			5			3,492			(2		)	3,500
	Operating income (loss)	(5		)	(5		)	1,585			—			1,575
	Equity in earnings of unconsolidated affiliates	—			—			382			—			382
	Equity in earnings of consolidated subsidiaries	917			1,377			—			(2,294		)	—
	Other income and expenses, net	(2		)	3			82			—			83
	Interest expense	—			190			435			—			625
	Earnings from continuing operations before income taxes	910			1,185			1,614			(2,294		)	1,415
	Income tax expense (benefit) from continuing operations	(31		)	268			133			—			370
	Income from continuing operations	941			917			1,481			(2,294		)	1,045
	Income (loss) from discontinued operations, net of tax	(1		)	—			3			—			2
	Net income	940			917			1,484			(2,294		)	1,047
	Net income — noncontrolling interests	—			—			107			—			107
	Net income — controlling interests	$	940		$	917		$	1,377		$	(2,294	)	$	940
	Spectra Energy Corp
	Condensed Consolidating Statements of Comprehensive Income
	(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp
Year Ended December 31, 2014
Net income	$	1,082		$	1,054		$	1,852		$	(2,705	)	$	1,283
Other comprehensive income (loss)	9			1			(596		)	—			(586		)
Total comprehensive income, net of tax	1,091			1,055			1,256			(2,705		)	697
Less: comprehensive income — noncontrolling interests	—			—			194			—			194
Comprehensive income — controlling interests	$	1,091		$	1,055		$	1,062		$	(2,705	)	$	503
Year Ended December 31, 2013
Net income	$	1,038		$	1,015		$	1,770		$	(2,664	)	$	1,159
Other comprehensive income (loss)	69			2			(346		)	—			(275		)
Total comprehensive income, net of tax	1,107			1,017			1,424			(2,664		)	884
Less: comprehensive income — noncontrolling interests	—			—			114			—			114
Comprehensive income — controlling interests	$	1,107		$	1,017		$	1,310		$	(2,664	)	$	770
Year Ended December 31, 2012
Net income	$	940		$	917		$	1,484		$	(2,294	)	$	1,047
Other comprehensive income (loss)	(12		)	3			248			—			239
Total comprehensive income, net of tax	928			920			1,732			(2,294		)	1,286
Less: comprehensive income — noncontrolling interests	—			—			110			—			110
Comprehensive income — controlling interests	$	928		$	920		$	1,622		$	(2,294	)	$	1,176
Spectra Energy Corp
Condensed Consolidating Balance Sheet
December 31, 2014
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp
Cash and cash equivalents	$	—		$	1		$	214		$	—		$	215
Receivables — consolidated subsidiaries	18			—			11			(29		)	—
Receivables — other	2			—			1,334			—			1,336
Other current assets	71			2			708			—			781
Total current assets	91			3			2,267			(29		)	2,332
Investments in and loans to unconsolidated affiliates	—			—			2,966			—			2,966
Investments in consolidated subsidiaries	14,531			20,562			—			(35,093		)	—
Advances receivable — consolidated subsidiaries	—			4,683			898			(5,581		)	—
Notes receivable — consolidated subsidiaries	—			—			3,198			(3,198		)	—
Goodwill	—			—			4,714			—			4,714
Other assets	38			22			267			—			327
Net property, plant and equipment	—			—			22,307			—			22,307
Regulatory assets and deferred debits	4			15			1,375			—			1,394
Total Assets	$	14,664		$	25,285		$	37,992		$	(43,901	)	$	34,040
Accounts payable	$	3		$	—		$	455		$	—		$	458
Accounts payable — consolidated subsidiaries	—			17			12			(29		)	—
Commercial paper	—			398			1,185			—			1,583
Short-term borrowings — consolidated subsidiaries	—			398			—			(398		)	—
Taxes accrued	5			—			86			—			91
Current maturities of long-term debt	—			—			327			—			327
Other current liabilities	96			54			1,200			—			1,350
Total current liabilities	104			867			3,265			(427		)	3,809
Long-term debt	—			2,900			9,869			—			12,769
Advances payable — consolidated subsidiaries	5,581			—			—			(5,581		)	—
Notes payable — consolidated subsidiaries	—			2,800			—			(2,800		)	—
Deferred credits and other liabilities	819			4,187			1,800			—			6,806
Preferred stock of subsidiaries	—			—			258			—			258
Equity
Controlling interests	8,160			14,531			20,562			(35,093		)	8,160
Noncontrolling interests	—			—			2,238			—			2,238
Total equity	8,160			14,531			22,800			(35,093		)	10,398
Total Liabilities and Equity	$	14,664		$	25,285		$	37,992		$	(43,901	)	$	34,040
Spectra Energy Corp
Condensed Consolidating Balance Sheet
December 31, 2013
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp
Cash and cash equivalents	$	—		$	12		$	189		$	—		$	201
Receivables — consolidated subsidiaries	176			394			—			(570		)	—
Receivables — other	1			—			1,335			—			1,336
Other current assets	40			15			489			—			544
Total current assets	217			421			2,013			(570		)	2,081
Investments in and loans to unconsolidated affiliates	—			—			3,043			—			3,043
Investments in consolidated subsidiaries	13,244			19,403			—			(32,647		)	—
Advances receivable — consolidated subsidiaries	—			4,038			677			(4,715		)	—
Notes receivable — consolidated subsidiaries	—			—			3,215			(3,215		)	—
Goodwill	—			—			4,810			—			4,810
Other assets	39			30			316			—			385
Net property, plant and equipment	—			—			21,829			—			21,829
Regulatory assets and deferred debits	3			17			1,365			—			1,385
Total Assets	$	13,503		$	23,909		$	37,268		$	(41,147	)	$	33,533
Accounts payable	$	4		$	—		$	436		$	—		$	440
Accounts payable — consolidated subsidiaries	89			—			481			(570		)	—
Commercial paper	—			344			688			—			1,032
Short-term borrowings — consolidated subsidiaries	—			415			—			(415		)	—
Taxes accrued	4			—			68			—			72
Current maturities of long-term debt	—			557			640			—			1,197
Other current liabilities	81			75			1,142			—			1,298
Total current liabilities	178			1,391			3,455			(985		)	4,039
Long-term debt	—			2,605			9,883			—			12,488
Advances payable — consolidated subsidiaries	4,715			—			—			(4,715		)	—
Notes payable — consolidated subsidiaries	—			2,800			—			(2,800		)	—
Deferred credits and other liabilities	116			3,869			2,440			—			6,425
Preferred stock of subsidiaries	—			—			258			—			258
Equity
Controlling interests	8,494			13,244			19,403			(32,647		)	8,494
Noncontrolling interests	—			—			1,829			—			1,829
Total equity	8,494			13,244			21,232			(32,647		)	10,323
Total Liabilities and Equity	$	13,503		$	23,909		$	37,268		$	(41,147	)	$	33,533
Spectra Energy Corp
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2014
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,082		$	1,054		$	1,852		$	(2,705	)	$	1,283
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	—			—			809			—			809
Equity in earnings of unconsolidated affiliates	—			—			(361		)	—			(361		)
Equity in earnings of consolidated subsidiaries	(1,054		)	(1,651		)	—			2,705			—
Distributions received from unconsolidated affiliates	—			—			380			—			380
Other	14			304			(208		)	—			110
Net cash provided by (used in) operating activities	42			(293		)	2,472			—			2,221
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	—			—			(2,028		)	—			(2,028		)
Investments in and loans to unconsolidated affiliates	—			—			(259		)	—			(259		)
Purchases of held-to-maturity securities	—			—			(790		)	—			(790		)
Proceeds from sales and maturities of held-to-maturity securities	—			—			815			—			815
Purchases of available-for-sale securities	—			—			(13		)	—			(13		)
Proceeds from sales and maturities of available-for-sale securities	—			—			7			—			7
Distributions received from unconsolidated affiliates	—			—			266			—			266
Advances from affiliates	92			495			—			(587		)	—
Other changes in restricted funds	—			—			(1		)	—			(1		)
Net cash provided by (used in) investing activities	92			495			(2,003		)	(587		)	(2,003		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			300			728			—			1,028
Payments for the redemption of long-term debt	—			(557		)	(627		)	—			(1,184		)
Net increase in commercial paper	—			54			520			—			574
Distributions to noncontrolling interests	—			—			(175		)	—			(175		)
Contributions from noncontrolling interests	—			—			145			—			145
Proceeds from the issuance of SEP common units	—			—			327			—			327
Dividends paid on common stock	(925		)	—			—			—			(925		)
Distributions and advances from (to) affiliates	777			(10		)	(1,354		)	587			—
Other	14			—			(3		)	—			11
Net cash used in financing activities	(134		)	(213		)	(439		)	587			(199		)
Effect of exchange rate changes on cash	—			—			(5		)	—			(5		)
Net increase (decrease) in cash and cash equivalents	—			(11		)	25			—			14
Cash and cash equivalents at beginning of period	—			12			189			—			201
Cash and cash equivalents at end of period	$	—		$	1		$	214		$	—		$	215
Spectra Energy Corp
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2013
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital (a)			Subsidiaries (a)
	Corp
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,038		$	1,015		$	1,770		$	(2,664	)	$	1,159
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	—			—			787			—			787
Equity in earnings of unconsolidated affiliates	—			—			(445		)	—			(445		)
Equity in earnings of consolidated subsidiaries	(1,015		)	(1,649		)	—			2,664			—
Distributions received from unconsolidated affiliates	—			—			324			—			324
Other	(2		)	478			(271		)	—			205
Net cash provided by (used in) operating activities	21			(156		)	2,165			—			2,030
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	—			—			(1,947		)	—			(1,947		)
Investments in and loans to unconsolidated affiliates	—			—			(312		)	—			(312		)
Acquisitions, net of cash acquired	—			—			(1,254		)	—			(1,254		)
Purchases of held-to-maturity securities	—			—			(985		)	—			(985		)
Proceeds from sales and maturities of held-to-maturity securities	—			—			1,023			—			1,023
Purchases of available-for-sale securities	—			—			(5,878		)	—			(5,878		)
Proceeds from sales and maturities of available-for-sale securities	—			—			6,024			—			6,024
Distributions received from unconsolidated affiliates	—			—			87			—			87
Advances to affiliates	(75		)	(1,856		)	—			1,931			—
Loan to unconsolidated affiliate	—			—			(71		)	—			(71		)
Repayment of loan to unconsolidated affiliate	—			71			—			—			71
Other changes in restricted funds	—			—			2			—			2
Other	—			—			4			—			4
Net cash used in investing activities	(75		)	(1,785		)	(3,307		)	1,931			(3,236		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			1,848			2,524			—			4,372
Payments for the redemption of long-term debt	—			(1,944		)	(195		)	—			(2,139		)
Net decrease in commercial paper	—			(170		)	(36		)	—			(206		)
Net increase in short-term borrowings – consolidated subsidiaries	—			(497		)	—			497			—
Distributions to noncontrolling interests	—			—			(144		)	—			(144		)
Contributions from noncontrolling interests	—			—			23			—			23
Proceeds from the issuance of SEP common units	—			—			214			—			214
Dividends paid on common stock	(821		)	—			—			—			(821		)
Distributions and advances from (to) affiliates	847			2,718			(1,137		)	(2,428		)	—
Other	28			(5		)	(6		)	—			17
Net cash provided by financing activities	54			1,950			1,243			(1,931		)	1,316
Effect of exchange rate changes on cash	—			—			(3		)	—			(3		)
Net increase in cash and cash equivalents	—			9			98			—			107
Cash and cash equivalents at beginning of period	—			3			91			—			94
Cash and cash equivalents at end of period	$	—		$	12		$	189		$	—		$	201
____________
(a)	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
Spectra Energy Corp
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2012
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp			(a)			(a)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	940		$	917		$	1,484		$	(2,294	)	$	1,047
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	—			—			760			—			760
Equity in earnings of unconsolidated affiliates	—			—			(382		)	—			(382		)
Equity in earnings of consolidated subsidiaries	(917		)	(1,377		)	—			2,294			—
Distributions received from unconsolidated affiliates	—			—			307			—			307
Other	(86		)	246			46			—			206
Net cash provided by (used in) operating activities	(63		)	(214		)	2,215			—			1,938
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	—			—			(2,025		)	—			(2,025		)
Investments in and loans to unconsolidated affiliates	—			—			(520		)	—			(520		)
Acquisitions, net of cash acquired	—			—			(30		)	—			(30		)
Purchases of held-to-maturity securities	—			—			(2,671		)	—			(2,671		)
Proceeds from sales and maturities of held-to-maturity securities	—			—			2,578			—			2,578
Purchases of available-for-sale securities	—			—			(644		)	—			(644		)
Proceeds from sales and maturities of available-for-sale securities	—			—			514			—			514
Distributions received from unconsolidated affiliates	—			—			17			—			17
Advances from (to) affiliates	(163		)	(335		)	888			(390		)	—
Other changes in restricted funds	—			—			93			—			93
Other	—			—			14			—			14
Net cash used in investing activities	(163		)	(335		)	(1,786		)	(390		)	(2,674		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			—			1,301			—			1,301
Payments for the redemption of long-term debt	—			—			(525		)	—			(525		)
Net increase (decrease) in commercial paper	—			(238		)	437			—			199
Net increase in short-term borrowings - consolidated subsidiaries	—			322			—			(322		)	—
Distributions to noncontrolling interests	—			—			(120		)	—			(120		)
Proceeds from the issuance of Spectra Energy common stock	382			—			—			—			382
Proceeds from the issuance of SEP common units	—			—			145			—			145
Dividends paid on common stock	(753		)	—			—			—			(753		)
Distributions and advances from (to) affiliates	564			466			(1,742		)	712			—
Other	33			—			(8		)	—			25
Net cash provided by (used in) financing activities	226			550			(512		)	390			654
Effect of exchange rate changes on cash	—			—			2			—			2
Net increase (decrease) in cash and cash equivalents	—			1			(81		)	—			(80		)
Cash and cash equivalents at beginning of period	—			2			172			—			174
Cash and cash equivalents at end of period	$	—		$	3		$	91		$	—		$	94
____________
(a)	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited)
		First		Second		Third		Fourth		Total
		Quarter		Quarter		Quarter		Quarter
		(in millions, except per share amounts)
	2014
	Operating revenues	$	1,843	$	1,253	$	1,207	$	1,600	$	5,903
	Operating income	639		338		382		565		1,924
	Net income	467		188		254		374		1,283
	Net income — controlling interests	419		146		201		316		1,082
	Earnings per share (a)
	Basic	0.63		0.22		0.3		0.47		1.61
	Diluted	0.62		0.22		0.3		0.47		1.61
	2013
	Operating revenues	$	1,589	$	1,220	$	1,144	$	1,565	$	5,518
	Operating income	506		354		333		473		1,666
	Net income	370		226		292		271		1,159
	Net income — controlling interests	340		199		263		236		1,038
	Earnings per share (a)
	Basic	0.51		0.3		0.39		0.35		1.55
	Diluted	0.51		0.3		0.39		0.35		1.55
	___________
	(a)	Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to rounding.
	Unusual or Infrequent Items
	During the third and fourth quarters of 2013, we recorded transaction costs related to the U.S. Assets Dropdown and additional merger and acquisitions costs. These costs impacted operating income by $23 million, net income by $22 million and net income-controlling interests by $20 million in the third quarter of 2013, and operating income, net income and net income-controlling interests by $11 million the fourth quarter 2013.
	During the fourth quarter of 2013, we recorded income tax expense resulting from a change in state tax rate related to the U.S. Assets Dropdown, which impacted net income and net income-controlling by $31 million for the year ended .

SCHEDULE_IIVALUATION_AND_QUALI

SCHEDULE II-VALUATION AND QUALIFYING ACCOUNTS AND RESERVES	12 Months Ended
	Dec. 31, 2014
Valuation and Qualifying Accounts [Abstract]
SCHEDULE II-VALUATION AND QUALIFYING ACCOUNTS AND RESERVES	SPECTRA ENERGY CORP
	SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
		Balance at		Additions:				Deductions (a)		Balance at
		Beginning								End of
		of Period		Charged to		Charged to				Period
				Expense		Other
						Accounts
		(in millions)
	31-Dec-14
	Allowance for doubtful accounts	$	10	$	6	$	—	$	5	$	11
	Other (b)	164		29		—		80		113
		$	174	$	35	$	—	$	85	$	124
	31-Dec-13
	Allowance for doubtful accounts	$	13	$	7	$	—	$	10	$	10
	Other (b)	181		21		—		38		164
		$	194	$	28	$	—	$	48	$	174
	31-Dec-12
	Allowance for doubtful accounts	$	14	$	10	$	1	$	12	$	13
	Other (b)	171		64		—		54		181
		$	185	$	74	$	1	$	66	$	194
	_________
	(a)	Principally cash payments and reserve reversals.
	(b)	Principally income tax, insurance-related, litigation and other reserves, included primarily in Deferred Credits and Other Liabilities—Regulatory and Other on the Consolidated Balance Sheets.

Summary_of_Operations_and_Sign1

Summary of Operations and Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Use of Estimates	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 Consolidated Financial Statements and Notes to Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.
Fair Value Measurements	Fair Value Measurements. We measure the fair value of financial assets and liabilities by maximizing the use of observable inputs and minimizing the use of unobservable inputs. Fair value is the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.
Cost-Based Regulation	Cost-Based Regulation. The economic effects of regulation can result in a regulated company recording assets for costs that have been or are expected to be approved for recovery from customers or recording liabilities for amounts that are expected to be returned to customers or for instances where the regulator provides current rates that are intended to recover costs that are expected to be incurred in the future. Accordingly, we record assets and liabilities that result from the regulated ratemaking process that may not be recorded under GAAP for non-regulated entities. We continually assess whether regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes and recent rate orders to other regulated entities. Based on this assessment, we believe our existing regulatory assets are probable of recovery. These regulatory assets and liabilities are mostly classified in the Consolidated Balance Sheets as Regulatory Assets and Deferred Debits, and Deferred Credits and Other Liabilities — Regulatory and Other. We evaluate our regulated assets, and consider factors such as regulatory changes and the effect of competition. If cost-based regulation ends or competition increases, we may have to reduce our asset balances to reflect a market basis less than cost and write-off the associated regulatory assets and liabilities. See Note 5 for further discussion.
Foreign Currency Translation	Foreign Currency Translation. The Canadian dollar has been determined to be the functional currency of our Canadian operations based on an assessment of the economic circumstances of those operations. Assets and liabilities of our Canadian operations are translated into U.S. dollars at current exchange rates. Translation adjustments resulting from fluctuations in exchange rates are included as a separate component of Other Comprehensive Income on the Consolidated Statements of Comprehensive Income. Revenue and expense accounts of these operations are translated at average monthly exchange rates prevailing during the periods. Gains and losses arising from transactions denominated in currencies other than the functional currency are included in the results of operations of the period in which they occur. Foreign currency transaction gains (losses) totaled $3 million in 2014, $1 million in 2013 and $(3) million in 2012, and are included in Other Income and Expenses, Net on the Consolidated Statements of Operations. Deferred U.S. taxes related to translation gains and losses have not been provided on those Canadian operations that we expect the earnings to be indefinitely reinvested.
Revenue Recognition	Revenue Recognition. Revenues from the transmission, storage, processing, distribution and sales of natural gas, from the sales of NGLs and from the transportation and storage of crude oil are generally recognized when either the service is provided or the product is delivered. Revenues related to these services provided or products delivered but not yet billed are estimated each month. These estimates are generally based on contract data, regulatory information, estimated distribution usage based on historical data adjusted for heating degree days, commodity prices and preliminary throughput and allocation measurements. Final bills for the current month are billed and collected in the following month. Differences between actual and estimated unbilled revenues are immaterial. There were no customers accounting for 10% or more of consolidated revenues during 2014, 2013 or 2012. We also have certain customer contracts with billed amounts that decline annually over the terms of the contracts. Differences between the amounts billed and recognized are deferred on the Consolidated Balance Sheets.
Stock-Based Compensation	Stock-Based Compensation. For employee awards, equity-classified and liability-classified stock-based compensation cost is measured at the grant date based on the fair value of the award. Liability-classified stock-based compensation cost is remeasured at each reporting period until settlement. Related compensation expense is recognized over the requisite service period, which generally begins on the date the award is granted through the earlier of the date the award vests, the date the employee becomes retirement-eligible or the date the market or performance condition of the award is met. Awards, including stock options, granted to employees that are retirement-eligible are deemed to have vested immediately upon issuance, and therefore, compensation cost for those awards is recognized on the date such awards are granted. See Note 24 for further discussion.
Pension and Other Post-Retirement Benefits	Pension and Other Post-Retirement Benefits. We fully recognize the overfunded or underfunded status of our consolidating subsidiaries’ pension and other post-retirement benefit plans as Investments and Other Assets - Other, Current Liabilities - Other or Deferred Credits and Other Liabilities - Regulatory and Other in the Consolidated Balance Sheets, as appropriate. A plan’s funded status is the difference between the fair value of plan assets and the plan’s projected benefit obligation. We record deferred plan costs and income (unrecognized losses and gains, and unrecognized prior service costs and credits) in Accumulated Other Comprehensive Income (AOCI) on the Consolidated Statements of Equity, until they are amortized and recognized as a component of benefit expense within Operating, Maintenance and Other in the Consolidated Statements of Operations. See Note 25 for further discussion.
Allowance for Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC). AFUDC, which represents the estimated debt and equity costs of capital funds necessary to finance the construction of certain new regulated facilities, consists of two components, an equity component and an interest expense component. The equity component is a non-cash item. After construction is completed, we are permitted to recover these costs through inclusion in the rate base and in the depreciation provision. AFUDC is capitalized as a component of Property, Plant and Equipment - Cost in the Consolidated Balance Sheets, with offsetting credits to the Consolidated Statements of Operations through Other Income and Expenses, Net for the equity component and Interest Expense for the interest expense component. The total amount of AFUDC included in the Consolidated Statements of Operations was $72 million in 2014 (an equity component of $53 million and an interest expense component of $19 million), $155 million in 2013 (an equity component of $105 million and an interest expense component of $50 million) and $131 million in 2012 (an equity component of $85 million and an interest expense component of $46 million).
Income Taxes	Income Taxes. Deferred income taxes are recognized for differences between the financial reporting and tax bases of assets and liabilities at enacted statutory tax rates in effect for the years in which the differences are expected to reverse. The effect on deferred taxes of a change in tax rates is recognized in income in the period that includes the enactment date. Actual income taxes could vary from these estimates due to future changes in income tax law or results from the final review of tax returns by federal, state or foreign tax authorities.
	Financial statement effects on tax positions are recognized in the period in which it is more likely than not that the position will be sustained upon examination, the position is effectively settled or when the statute of limitations to challenge the position has expired. Interest and penalties related to unrecognized tax benefits are recorded as interest expense and other expense, respectively.
Cash and Cash Equivalents	Cash and Cash Equivalents. Highly liquid investments with original maturities of three months or less at the date of acquisition, except for the investments that were pledged as collateral against long-term debt as discussed in Note 16 and any investments that are considered restricted funds, are considered cash equivalents.
Inventory	Inventory. Inventory consists of natural gas and NGLs held in storage for transmission and processing, and also includes materials and supplies. Natural gas inventories primarily relate to the Distribution segment in Canada and are valued at costs approved by the regulator, the Ontario Energy Board (OEB). The difference between the approved price and the actual cost of gas purchased is recorded in either accounts receivable or other current liabilities, as appropriate, for future disposition with customers, subject to approval by the OEB. The remaining inventory is recorded at the lower of cost or market, primarily using average cost.
Natural Gas Imbalances	Natural Gas Imbalances. The Consolidated Balance Sheets include in-kind balances as a result of differences in gas volumes received and delivered for customers. Since settlement of certain imbalances is in-kind, changes in their balances do not have an effect on our Consolidated Statements of Cash Flows. Receivables include $642 million and $606 million as of December 31, 2014 and December 31, 2013, respectively, and Other Current Liabilities include $634 million and $575 million as of December 31, 2014 and December 31, 2013, respectively, related to gas imbalances. Most natural gas volumes owed to or by us are valued at natural gas market index prices as of the balance sheet dates.
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. In addition, credit default swap rates are used to develop the adjustment for credit risk embedded in our positions. We believe that since some of the inputs and assumptions for the calculations of fair value are derived from observable market data, a Level 2 classification is appropriate.
	Level 3 Valuation Techniques
	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.
	The derivative financial instruments reported in Level 3 at December 31, 2014 primarily consist of NGL revenue swap contracts related to the Empress assets in Western Canada Transmission & Processing. As of December 31, 2014, we reported certain of our natural gas basis swaps at fair value using Level 3 inputs due to such derivatives not having observable market prices for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations whose contract length extends into unobservable periods.
	The fair value of these natural gas basis swaps is determined using a discounted cash flow valuation technique based on a forward commodity basis curve. For these derivatives, the primary input to the valuation model is the forward commodity basis curve, which is based on observable or public data sources and extrapolated when observable prices are not available.
	The significant unobservable inputs used in the fair value measurements of our Level 3 derivatives are the forward natural gas basis curves, for which a significant portion of the derivative’s term is beyond available forward pricing. At December 31, 2014, a 10¢ per gallon movement in underlying forward NGL prices would affect the estimated fair value of our NGL derivatives by $16 million. This calculated amount does not take into account any other changes to the fair value measurement calculation.
Risk Management and Hedging Activities and Financial Instruments	Risk Management and Hedging Activities and Financial Instruments. Currently, our use of derivative instruments is primarily limited to interest rate positions and commodity pricing. All derivative instruments that do not qualify for the normal purchases and normal sales exception are recorded on the Consolidated Balance Sheets at fair value. Cash inflows and outflows related to derivative instruments are a component of Cash Flows From Operating Activities in the accompanying Consolidated Statements of Cash Flows.
	Cash Flow and Fair Value Hedges. Qualifying energy commodity and other derivatives may be designated as either a hedge of a forecasted transaction (cash flow hedge) or a hedge of a recognized asset, liability or firm commitment (fair value hedge). For all hedge contracts, we prepare documentation of the hedge in accordance with accounting standards and assess whether the hedge contract is highly effective using regression analysis, both at inception and on a quarterly basis, in offsetting changes in cash flows or fair values of hedged items. We document hedging activity by instrument type (futures or swaps) and risk management strategy (commodity price risk or interest rate risk).
	For derivatives designated as fair value hedges, we recognize the gain or loss on the derivative instrument, as well as the offsetting gain or loss on the hedged item in earnings, to the extent effective, in the current period. In the event the hedge is not effective, there is no offsetting gain or loss recognized in earnings for the hedged item. All derivatives designated and accounted for as hedges are classified in the same category as the item being hedged in the Consolidated Statements of Cash Flows. All components of each derivative gain or loss are included in the assessment of hedge effectiveness.
Investments	Investments. We may actively invest a portion of our available cash and restricted funds balances in various financial instruments, including taxable or tax-exempt debt securities. In addition, we invest in short-term money market securities, some of which are restricted due to debt collateral or insurance requirements. Investments in available-for-sale (AFS) securities are carried at fair value and investments in held-to-maturity (HTM) securities are carried at cost. Investments in money market securities are also accounted for at fair value. Realized gains and losses, and dividend and interest income related to these securities, including any amortization of discounts or premiums arising at acquisition, are included in earnings. The costs of securities sold are determined using the specific identification method. Purchases and sales of AFS and HTM securities are presented on a gross basis within Cash Flows From Investing Activities in the accompanying Consolidated Statements of Cash Flows.
Goodwill	Goodwill. We perform our goodwill impairment test annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. No impairments of goodwill were recorded in 2014, 2013 or 2012. See Note 12 for further discussion.
	We perform our annual review for goodwill impairment at the reporting unit level, which is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. We determined that our reporting units are equivalent to our reportable segments, except for the reporting units of our Western Canada Transmission & Processing and Spectra Energy Partners reportable segments, which are one level below.
	As permitted under accounting guidance on testing goodwill for impairment, we perform either a qualitative assessment or a quantitative assessment of each of our reporting units based on management’s judgment. With respect to our qualitative assessments, we consider events and circumstances specific to us, such as macroeconomic conditions, industry and market considerations, cost factors and overall financial performance, when evaluating whether it is more likely than not that the fair values of our reporting units are less than their respective carrying amounts.
	In connection with our quantitative assessments, we primarily use a discounted cash flow analysis to determine the fair
	values of those reporting units. Key assumptions in the determination of fair value included the use of an appropriate discount
	rate and estimated future cash flows. In estimating cash flows, we incorporate expected long-term growth rates in key markets
	served by our operations, regulatory stability, the ability to renew contracts, commodity prices (where appropriate) and foreign
	currency exchange rates, as well as other factors that affect our reporting units’ revenue, expense and capital expenditure
	projections. If the carrying amount of the reporting unit exceeds its fair value, a comparison of the fair value and carrying value
	of the goodwill of that reporting unit needs to be performed. If the carrying value of the goodwill of a reporting unit exceeds
	the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to the excess. Additional
	impairment tests are performed between the annual reviews if events or changes in circumstances make it more likely than not
	that the fair value of a reporting unit is below its carrying amount.
Property, Plant and Equipment	Property, Plant and Equipment. Property, plant and equipment is stated at historical cost less accumulated depreciation. We capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Indirect costs include general engineering, taxes and the cost of funds used during construction. The costs of renewals and betterments that extend the useful life or increase the expected output of property, plant and equipment are also capitalized. The costs of repairs, replacements and major maintenance projects that do not extend the useful life or increase the expected output of property, plant and equipment are expensed as incurred. Depreciation is generally computed over the asset’s estimated useful life using the straight-line method.
	When we retire regulated property, plant and equipment, we charge the original cost plus the cost of retirement, less salvage value, to accumulated depreciation and amortization. When we sell entire regulated operating units or retire non-regulated properties, the cost is removed from the property account and the related accumulated depreciation and amortization accounts are reduced. Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body.
Preliminary Project Costs	Preliminary Project Costs. Project development costs, including expenditures for preliminary surveys, plans, investigations, environmental studies, regulatory applications and other costs incurred for the purpose of determining the feasibility of capital expansion projects, are capitalized for rate-regulated enterprises when it is determined that recovery of such costs through regulated revenues of the completed project is probable. Any inception-to-date costs of the project that were initially expensed are reversed and capitalized as Property, Plant and Equipment.
Long-Lived Asset Impairments	Long-Lived Asset Impairments. We evaluate whether long-lived assets, excluding goodwill, have been impaired when circumstances indicate the carrying value of those assets may not be recoverable. For such long-lived assets, an impairment exists when its carrying value exceeds the sum of estimates of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, a probability-weighted approach is used in developing estimates of future undiscounted cash flows. If the carrying value of the long-lived asset is not recoverable based on these estimated future undiscounted cash flows, an impairment loss is measured as the excess of the asset’s carrying value over its fair value, such that the asset’s carrying value is adjusted to its estimated fair value.
	We assess the fair value of long-lived assets using commonly accepted techniques and may use more than one source. Sources to determine fair value include, but are not limited to, recent third-party comparable sales, internally developed discounted cash flow analyses and analyses from outside advisors. Significant changes in market conditions resulting from events such as changes in natural gas available to our systems, the condition of an asset, a change in our intent to utilize the asset or a significant change in contracted revenues or regulatory recoveries would generally require us to reassess the cash flows related to the long-lived assets.
Asset Retirement Obligations	Asset Retirement Obligations. We recognize asset retirement obligations (AROs) for legal commitments associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made and is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset.
Unamortized Debt Premium, Discount and Expense	Unamortized Debt Premium, Discount and Expense. Premiums, discounts and expenses incurred with the issuance of outstanding long-term debt are amortized over the terms of the debt issues. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations to finance regulated assets and operations are amortized consistent with regulatory treatment of those items, where appropriate.
Environmental Expenditures	Environmental Expenditures. We expense environmental expenditures related to conditions caused by past operations that do not generate current or future revenues. Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Undiscounted liabilities are recorded when the necessity for environmental remediation becomes probable and the costs can be reasonably estimated, or when other potential environmental liabilities are reasonably estimable and probable.
Captive Insurance Reserves	Captive Insurance Reserves. We have captive insurance subsidiaries which provide insurance coverage to our consolidated subsidiaries as well as certain equity affiliates, on a limited basis, for various business risks and losses, such as workers compensation, property, business interruption and general liability. Liabilities include provisions for estimated losses incurred but not yet reported, as well as provisions for known claims which have been estimated on a claims-incurred basis. Incurred but not yet reported reserve estimates involve the use of assumptions and are based upon historical loss experience, industry data and other actuarial assumptions. Reserve estimates are adjusted in future periods as actual losses differ from historical experience.
Guarantees	Guarantees. Upon issuance or material modification of a guarantee made by us, we recognize a liability for the estimated fair value of the obligation we assume under that guarantee, if any. Fair value is estimated using a probability-weighted approach. We reduce the obligation over the term of the guarantee or related contract in a systematic and rational method as risk is reduced under the obligation.
Accounting For Sales of Stock by a Subsidiary	Accounting For Sales of Stock by a Subsidiary. Sales of stock by a consolidated subsidiary are accounted for as equity transactions in those instances where a change in control does not take place.
Segment Reporting	Segment Reporting. Operating segments are components of an enterprise for which separate financial information is available and evaluated regularly by the chief operating decision maker in deciding how to allocate resources and evaluate performance. Two or more operating segments may be aggregated into a single reportable segment provided certain criteria are met. There is no such aggregation within our defined business segments. A description of our reportable segments, consistent with how business results are reported internally to management, and the disclosure of segment information is presented in Note 4.
Consolidated Statements of Cash Flows	Consolidated Statements of Cash Flows. Cash flows from discontinued operations are combined with cash flows from continuing operations within operating, investing and financing cash flows. Cash received from insurance proceeds are classified depending on the activity that resulted in the insurance proceeds. For example, business interruption insurance proceeds are included as a component of operating activities while insurance proceeds from damaged property are included as a component of investing activities. With respect to cash overdrafts, book overdrafts are included within operating cash flows while bank overdrafts, if any, are included within financing cash flows. Cash flows from borrowings and repayments under revolving credit facilities that had documented original maturities of 90 days or less are reported on a net basis as Net Increase (Decrease) in Revolving Credit Facilities Borrowings within financing activities.
Distributions from Unconsolidated Affiliates	Distributions from Unconsolidated Affiliates. We consider distributions received from unconsolidated affiliates which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and classify these amounts as Cash Flows From Operating Activities within the accompanying Consolidated Statements of Cash Flows. Cumulative distributions received in excess of cumulative equity in earnings subsequent to the date of investment are considered to be a return of investment and are classified as Cash Flows From Investing Activities.
New Accounting Pronouncements	New Accounting Pronouncements. The following new Accounting Standards Update (ASU) was adopted during 2014 and the effect of such adoption has been presented in the accompanying Consolidated Financial Statements:
	ASU No. 2013-11. In July 2013, the Financial Accounting Standards Board (FASB) issued ASU No. 2013-11, “Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (a Consensus of the FASB Emerging Issues Task Force),” which was issued to eliminate diversity in practice. This ASU requires entities to net unrecognized tax benefits against all same-jurisdiction net operating losses or tax credit carryforwards that would be used to settle the position with a tax authority. We adopted this standard on January 1, 2014. The adoption of this ASU did not have a material impact on our consolidated results of operations, financial position or cash flows.
	Pending. The following new accounting pronouncements were issued but not adopted as of December 31, 2014:
	ASU No. 2014-08. In April 2014, the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” This ASU revises the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have or will have a major effect on an entity’s operations and financial results, removing the lack of continuing involvement criteria and requiring discontinued operations reporting for the disposal of an equity method investment that meets the definition of discontinued operations. The update also requires expanded disclosures for discontinued operations, and disclosure of pretax profit or loss of certain individually significant components of an entity that do not qualify for discontinued operations reporting. This ASU was effective for us on January 1, 2015 and had no impact on our consolidated results of operations, financial position or cash flows.
	ASU No. 2014-09. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606)” which supersedes the revenue recognition requirements of “Revenue Recognition (Topic 605)” and clarifies the principles of recognizing revenue. This ASU is effective for us January 1, 2017. We are currently evaluating this ASU and its potential impact on us.
	2013. There were no significant accounting pronouncements issued during 2013 that had a material impact on our consolidated results of operations, financial position or cash flows.
	2012. There were no significant accounting pronouncements issued during 2012 that had a material impact on our consolidated results of operations, financial position or cash flows.

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Summary of Fair Values of Assets and Liabilities Acquired	The following table summarizes the fair values of the assets and liabilities acquired as of the date of the acquisition.
		Purchase Price Allocation
		(in millions)
	Cash purchase price	$	1,250
	Working capital and other purchase adjustments	71
	Total	1,321
	Cash	67
	Receivables	25
	Other current assets	9
	Property, plant and equipment	1,251
	Accounts payable	(18		)
	Other current liabilities	(17		)
	Deferred credits and other liabilities	(259		)
	Long-term debt, including current portion	(260		)
	Total assets acquired/liabilities assumed	798
	Goodwill	$	523

Business_Segments_Tables

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Business Segment Data	Business Segment Data
		Unaffiliated Revenues		Intersegment			Total			Segment EBITDA/			Depreciation		Capital and		Assets
				Revenues			Operating			Consolidated			and		Investment
							Revenues (a)			Earnings			Amortization (a)		Expenditures (b,c)
										from Continuing
										Operations before
										Income Taxes (a)
		(in millions)
	2014
	Spectra Energy Partners	$	2,269	$	—		$	2,269		$	1,669		$	290	$	1,241	$	17,865
	Distribution	1,843		—			1,843			552			192		427		6,064
	Western Canada Transmission & Processing	1,781		121			1,902			754			271		473		6,916
	Field Services	—		—			—			217			—		—		1,345
	Total reportable segments	5,893		121			6,014			3,192			753		2,141		32,190
	Other	10		62			72			(58		)	43		146		1,908
	Eliminations	—		(183		)	(183		)	—			—		—		(58		)
	Depreciation and amortization	—		—			—			796			—		—		—
	Interest expense	—		—			—			679			—		—		—
	Interest income and other	—		—			—			6			—		—		—
	Total consolidated	$	5,903	$	—		$	5,903		$	1,665		$	796	$	2,287	$	34,040
	2013
	Spectra Energy Partners	$	1,964	$	1		$	1,965		$	1,433		$	263	$	1,299	$	16,800
	Distribution	1,848		—			1,848			574			199		357		6,009
	Western Canada Transmission & Processing	1,694		73			1,767			736			272		561		7,160
	Field Services	—		—			—			343			—		—		1,365
	Total reportable segments	5,506		74			5,580			3,086			734		2,217		31,334
	Other	12		60			72			(86		)	38		42		2,698
	Eliminations	—		(134		)	(134		)	—			—		—		(499		)
	Depreciation and amortization	—		—			—			772			—		—		—
	Interest expense	—		—			—			657			—		—		—
	Interest income and other	—		—			—			7			—		—		—
	Total consolidated	$	5,518	$	—		$	5,518		$	1,578		$	772	$	2,259	$	33,533
	2012
	Spectra Energy Partners	$	1,754	$	—		$	1,754		$	1,259		$	232	$	1,443	$	13,856
	Distribution	1,666		—			1,666			587			213		276		5,842
	Western Canada Transmission & Processing	1,645		34			1,679			694			245		760		7,226
	Field Services	—		—			—			279			—		—		1,235
	Total reportable segments	5,065		34			5,099			2,819			690		2,479		28,159
	Other	10		79			89			(36		)	56		66		2,967
	Eliminations	—		(113		)	(113		)	—			—		—		(539		)
	Depreciation and amortization	—		—			—			746			—		—		—
	Interest expense	—		—			—			625			—		—		—
	Interest income and other	—		—			—			3			—		—		—
	Total consolidated	$	5,075	$	—		$	5,075		$	1,415		$	746	$	2,545	$	30,587
	__________
	(a)	Excludes amounts associated with entities included in discontinued operations.
	(b)	Excludes the $1,254 million cash outlay for the acquisition of Express-Platte in March 2013 and $30 million paid in 2012 for amounts previously withheld from the purchase price consideration of the acquisition of Bobcat in 2010, all part of Spectra Energy Partners.
	(c)	Excludes a $71 million loan to an unconsolidated affiliate in 2013 at Spectra Energy Partners.
Geographic Data	Geographic Data
		U.S.		Canada			Consolidated
		(in millions)
	2014
	Consolidated revenues	$	2,212	$	3,691		$	5,903
	Consolidated long-lived assets	15,859		12,732			28,591
	2013
	Consolidated revenues	1,926		3,592			5,518
	Consolidated long-lived assets	14,993		13,264			28,257
	2012
	Consolidated revenues (a)	1,762		3,313			5,075
	Consolidated long-lived assets	10,952		14,875			25,827
	__________
	(a)	Excludes revenues associated with businesses included in discontinued operations.

Regulatory_Matters_Tables

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2014
Regulated Operations [Abstract]
Regulatory Assets and Liabilities	We record assets and liabilities that result from the regulated ratemaking process that would not be recorded under GAAP for non-regulated entities. See Note 1 for further discussion.
		December 31,				Recovery/
						Refund
		2014		2013		Period Ends
		(in millions)
	Regulatory Assets (a,b)
	Net regulatory asset related to income taxes (c,d)	$	1,271	$	1,224	(e)
	Project development costs	10		14		2036
	Vacation accrual	22		21		(f)
	Deferred debt expense/premium (d)	31		32		(e)
	Under-recovery of fuel costs (g,h)	44		28		2015
	Gas purchase costs (h,i)	57		—		2015
	Other	59		57		(j)
	Total Regulatory Assets	$	1,494	$	1,376
	Regulatory Liabilities (b)
	Removal costs (d,k)	$	326	$	359	(l)
	FT-RAM optimization (m)	—		31		2014
	Gas purchase costs (i,m)	—		7		2014
	Pipeline rate credit (k)	25		27		(e)
	Over-recovery of fuel costs (i,m)	—		35		2014
	Other (d)	79		51		(j)
	Total Regulatory Liabilities	$	430	$	510
	_________
	(a)	Included in Regulatory Assets and Deferred Debits unless otherwise noted.
	(b)	All regulatory assets and liabilities are excluded from rate base unless otherwise noted.
	(c)	All amounts are expected to be included in future rate filings.
	(d)	All or a portion of the balance is included in rate base.
	(e)	Recovery/refund is over the life of the associated asset or liability.
	(f)	Recoverable in future periods.
	(g)	Amounts settled in cash annually through transportation rates in accordance with FERC gas tariffs.
	(h)	Included in Other Current Assets.
	(i)	Includes certain costs which are settled in cash annually through transportation rates in accordance with FERC and/or OEB gas tariffs.
	(j)	The majority of this balance has a recovery period of less than one year. The recovery/refund period for the remainder is currently unknown.
	(k)	Included in Deferred Credits and Other Liabilities — Regulatory and Other.
	(l)	Liability is extinguished as the associated assets are retired.
	(m)	Included in Other Current Liabilities.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Expense Components	Income Tax Expense Components
		2014			2013			2012
		(in millions)
	Current income taxes
	Federal	$	1		$	(32	)	$	102
	State	3			4			5
	Foreign	(10		)	26			52
	Total current income taxes	(6		)	(2		)	159
	Deferred income taxes
	Federal	335			353			174
	State	(17		)	69			33
	Foreign	70			(1		)	4
	Total deferred income taxes	388			421			211
	Income tax expense from continuing operations	382			419			370
	Income tax expense from discontinued operations	—			—			2
	Total income tax expense	$	382		$	419		$	372
Earnings from Continuing Operations before Income Taxes	Earnings from Continuing Operations before Income Taxes
		2014			2013			2012
		(in millions)
	Domestic	$	1,108		$	1,059		$	912
	Foreign	557			519			503
	Total earnings from continuing operations before income taxes	$	1,665		$	1,578		$	1,415
Reconciliation of Income Tax Expense at U.S. Federal Statutory Tax Rate to Actual Income Tax Expense from Continuing Operations	Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to Actual Income Tax Expense from Continuing Operations
		2014			2013			2012
		(in millions)
	Income tax expense, computed at the statutory rate of 35%	$	583		$	552		$	495
	State income tax, net of federal income tax effect	25			20			19
	Tax differential on foreign earnings	(125		)	(147		)	(110		)
	Noncontrolling interests	(70		)	(42		)	(37		)
	Valuation allowance	2			(3		)	1
	Revaluation of accumulated deferred state taxes	(25		)	31			—
	Other items, net	(8		)	8			2
	Total income tax expense from continuing operations	$	382		$	419		$	370
	Effective tax rate	22.9		%	26.6		%	26.1		%
Net Deferred Income Tax Liability Components	Net Deferred Income Tax Liability Components
		December 31,
		2014			2013
		(in millions)
	Deferred credits and other liabilities	$	225		$	242
	Other	211			291
	Total deferred income tax assets	436			533
	Valuation allowance	(29		)	(29		)
	Net deferred income tax assets	407			504
	Investments and other assets	(1,531		)	(1,004		)
	Accelerated depreciation rates	(3,875		)	(4,092		)
	Regulatory assets and deferred debits	(426		)	(383		)
	Total deferred income tax liabilities	(5,832		)	(5,479		)
	Total net deferred income tax liabilities	$	(5,425	)	$	(4,975	)
Deferred Tax Amounts Classified in Consolidated Balance Sheets	The above deferred tax amounts have been classified in the Consolidated Balance Sheets as follows:
		December 31,
		2014			2013
		(in millions)
	Other current assets	$	—		$	9
	Other current liabilities	(20		)	(16		)
	Deferred credits and other liabilities	(5,405		)	(4,968		)
	Total net deferred income tax liabilities	$	(5,425	)	$	(4,975	)
Reconciliation of Gross Unrecognized Income Tax Benefits	Reconciliation of Gross Unrecognized Income Tax Benefits
		2014			2013			2012
		(in millions)
	Balance at beginning of period	$	76		$	80		$	76
	Increases related to prior year tax positions	10			7			5
	Decreases related to prior year tax positions	(6		)	(17		)	—
	Increases related to current year tax positions	1			2			2
	Settlements	—			(3		)	(2		)
	Lapse of statute of limitations	(30		)	9			(2		)
	Foreign currency translation	(1		)	(2		)	1
	Balance at end of period	$	50		$	76		$	80

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Results Classified as Income from Discontinued Operations, Net of Tax in Consolidated Statements of Operations	The following table summarizes results classified as Income From Discontinued Operations, Net of Tax in the accompanying Consolidated Statements of Operations:
		2012
		(in millions)
	Operating revenues	$	99
	Pre-tax earnings	4
	Income tax expense	2
	Income from discontinued operations, net of tax	2

Earnings_per_Common_Share_Tabl

Earnings per Common Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Basic and Diluted EPS Calculations	The following table presents our basic and diluted EPS calculations:
		2014		2013		2012
		(in millions, except per-share amounts)
	Income from continuing operations, net of tax — controlling interests	$	1,082	$	1,038	$	938
	Income from discontinued operations, net of tax — controlling interests	—		—		2
	Net income — controlling interests	$	1,082	$	1,038	$	940
	Weighted-average common shares outstanding
	Basic	671		669		653
	Diluted	672		671		656
	Basic earnings per common share	$	1.61	$	1.55	$	1.44
	Diluted earnings per common share	$	1.61	$	1.55	$	1.43

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents the net of tax changes in AOCI by component and amounts reclassified out of AOCI to Net Income, excluding amounts attributable to noncontrolling interests:
		Foreign Currency Translation Adjustments			Pension and Post-retirement Benefit Plan Obligations				Gas Purchase Contract Hedges			Other			Total Accumulated Other Comprehensive Income
								(in millions)
	31-Dec-12	$	2,044		$	(507	)		$	(23	)	$	(5	)	$	1,509
	Reclassified to net income	—			—				6			1			7
	Other AOCI activity	(487		)	203				6			3			(275		)
	31-Dec-13	1,557			(304		)		(11		)	(1		)	1,241
	Reclassified to net income	—			—				4			1			5
	Other AOCI activity	(541		)	(47		)		4			—			(584		)
	31-Dec-14	$	1,016		$	(351	)		$	(3	)	$	—		$	662

Inventory_Tables

Inventory (Tables)	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Components of Inventory	The components of inventory are as follows:
		December 31,
		2014		2013
		(in millions)
	Natural gas	$	211	$	155
	NGLs	28		30
	Materials and supplies	74		78
	Total inventory	$	313	$	263

Investments_in_and_Loans_to_Un1

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Investments in and Advances to Affiliates, Schedule of Investments [Abstract]
Investments in and Loans to Unconsolidated Affiliates	Investments in and Loans to Unconsolidated Affiliates
		31-Dec-14									31-Dec-13
		Domestic			International			Total			Domestic			International			Total
		(in millions)
	Spectra Energy Partners	$	1,588		$	—		$	1,588		$	1,396		$	—		$	1,396
	Distribution	—			14			14			—			16			16
	Western Canada Transmission & Processing	—			18			18			—			66			66
	Field Services	1,345			—			1,345			1,365			—			1,365
	Other	1			—			1			200			—			200
	Total	$	2,934		$	32		$	2,966		$	2,961		$	82		$	3,043
Equity in Earnings of Unconsolidated Affiliates	Equity in Earnings of Unconsolidated Affiliates
		2014									2013									2012
		Domestic			International			Total			Domestic			International			Total			Domestic		International		Total
		(in millions)
	Spectra Energy Partners	$	133		$	—		$	133		$	90		$	—		$	90		$	89	$	—	$	89
	Distribution	—			1			1			—			1			1			—		—		—
	Western Canada Transmission & Processing	—			1			1			—			(1		)	(1		)	—		1		1
	Field Services	217			—			217			343			—			343			279		—		279
	Other	9			—			9			12			—			12			13		—		13
	Total	$	359		$	2		$	361		$	445		$	—		$	445		$	381	$	1	$	382
Summarized Statements of Operations of Unconsolidated Affiliates Presented at 100 Percent	Summarized Combined Financial Information of Unconsolidated Affiliates (Presented at 100%)
	Statements of Operations
		2014									2013									2012
		DCP			Other			Total			DCP			Other			Total			DCP		Other		Total
		Midstream									Midstream									Midstream
		(in millions)
	Operating revenues	$	14,013		$	744		$	14,757		$	12,038		$	558		$	12,596		$	10,171	$	511	$	10,682
	Operating expenses	13,262			319			13,581			11,230			261			11,491			9,427		217		9,644
	Operating income	751			425			1,176			808			297			1,105			744		294		1,038
	Net income	536			332			868			584			206			790			583		203		786
	Net income attributable to members’  interests	288			332			620			491			206			697			486		203		689
Summarized Balance Sheets of Unconsolidated Affiliates Presented at 100 Percent	Balance Sheets
		31-Dec-14									31-Dec-13
		DCP			Other			Total			DCP			Other			Total
		Midstream									Midstream
		(in millions)
	Current assets	$	1,380		$	241		$	1,621		$	1,663		$	248		$	1,911
	Non-current assets	12,299			5,358			17,657			11,058			5,448			16,506
	Current liabilities	(2,938		)	(632		)	(3,570		)	(3,114		)	(143		)	(3,257		)
	Non-current liabilities	(5,538		)	(1,197		)	(6,735		)	(5,218		)	(1,670		)	(6,888		)
	Equity — total	5,203			3,770			8,973			4,389			3,883			8,272
	Equity — noncontrolling interests	(2,578		)	—			(2,578		)	(1,725		)	—			(1,725		)
	Equity — controlling interests	$	2,625		$	3,770		$	6,395		$	2,664		$	3,883		$	6,547

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Components and Activity within Goodwill	The following table presents activity within goodwill based on the reporting unit determination:
		Spectra Energy Partners			Distribution			Western Canada			Total
								Transmission &
								Processing
		(in millions)
	31-Dec-12	$	2,814		$	878		$	821		$	4,513
	Acquisition of Express-Platte	486			—			—			486
	Foreign currency translation	(85		)	(54		)	(50		)	(189		)
	31-Dec-13	3,215			824			771			4,810
	Adjustment to acquisition of Express-Platte	37			—			—			37
	Foreign currency translation	(8		)	(65		)	(60		)	(133		)
	31-Dec-14	$	3,244		$	759		$	711		$	4,714
Goodwill Amounts Originating from Acquisition of Westcoast Energy Inc.	The following remaining goodwill amounts originating from the acquisition of Westcoast Energy, Inc. (Westcoast) in 2002 are included as segment assets within “Other” in the segment data presented in Note 4:
		December 31,
		2014			2013
		(in millions)
	Distribution	$	757		$	821
	Western Canada Transmission & Processing	677			736

Marketable_Securities_and_Rest1

Marketable Securities and Restricted Funds (Tables)	12 Months Ended
	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Estimated Fair Values of Available for Sale Securities	AFS Securities. AFS securities are as follows:
		Estimated Fair Value
		December 31,
		2014			2013
		(in millions)
	Corporate debt securities	$	23		$	18
	Money market funds	1			1
	Total available-for-sale securities	$	24		$	19
Fair Value, by Balance Sheet Grouping	Our AFS securities are classified on the Consolidated Balance Sheets as follows:
			Estimated Fair Value
			December 31,
			2014			2013
			(in millions)
	Restricted funds
	Investments and other assets—other		$	1		$	1
	Non-restricted funds
	Current assets—other		3			7
	Investments and other assets—other		20			11
	Total available-for-sale securities		$	24		$	19
	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.
		December 31,
		2014						2013
		Book			Approximate			Book		Approximate
		Value			Fair Value			Value		Fair Value
		(in millions)
	Note receivable, noncurrent (a)	$	71		$	71		$	71	$	71
	Long-term debt, including current maturities (b)	13,060			14,446			13,668		14,701
	__________
	(a)	Included within Investments in and Loans to Unconsolidated Affiliates.
	(b)	Excludes capital leases, unamortized items and fair value hedge carrying value adjustments.
Estimated Fair Values of Held to Maturity Marketable Securities	HTM Securities. All of our HTM securities are restricted funds and are as follows:
			Estimated Fair Value
			December 31,
	Description	Consolidated Balance Sheet Caption	2014			2013
			(in millions)
	Bankers acceptances	Current assets—other	$	38		$	35
	Canadian government securities	Current assets—other	30			34
	Money market funds	Current assets—other	3			3
	Canadian government securities	Investments and other assets—other	101			131
	Bankers acceptances	Investments and other assets—other	—			10
	Total held-to-maturity securities		$	172		$	213

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property Plant and Equipment
		Estimated		December 31,
		Useful Life		2014			2013
		(years)		(in millions)
	Plant
	Natural gas transmission	15–100		$	15,001		$	14,491
	Natural gas distribution	25–60		2,971			3,076
	Gathering and processing facilities	25–40		4,765			4,848
	Natural gas storage	10–122		2,162			2,113
	Crude oil transportation and storage	30–75		1,169			1,243
	Land rights and rights of way	21–122		568			562
	Other buildings and improvements	10–50		132			134
	Equipment	3–40		343			341
	Vehicles	5–20		114			115
	Land	—		150			128
	Construction in process	—		1,113			630
	Software	4–10		387			438
	Other	5–82		336			337
	Total property, plant and equipment			29,211			28,456
	Total accumulated depreciation			(6,543		)	(6,258		)
	Total accumulated amortization			(361		)	(369		)
	Total net property, plant and equipment			$	22,307		$	21,829
Estimated Amortization Expense for Next Five Years	Estimated amortization expense for the next five years follows:
		Estimated
		Amortization
		Expense
		(in millions)
	2015	$	80
	2016		68
	2017		57
	2018		44
	2019		34

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Changes in Asset Retirement Obligation Liabilities	Reconciliation of Changes in Asset Retirement Obligation Liabilities
		2014			2013
		(in millions)
	Balance at beginning of year	$	350		$	188
	Accretion expense	16			9
	Revisions in estimated cash flows (a)	72			172
	Foreign currency exchange impact	(28		)	(12		)
	Liabilities settled	(10		)	(7		)
	Balance at end of year (b)	$	400		$	350
	__________
	(a) Reflects revised assumptions regarding ARO Liabilities relating to asbestos abatement at Western Canada Transmission & Processing in 2014 and expected future costs of abandonments at Union Gas in 2013.
	(b)	Amounts included in Deferred Credits and Other Liabilities in the Consolidated Balance Sheets.

Debt_and_Credit_Facilities_Tab

Debt and Credit Facilities (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Summary of Debt and Related Terms
	Summary of Debt and Related Terms	December 31,
		2014				2013
	Spectra Energy Capital, LLC	(in millions)
	5.50% senior unsecured notes due March 2014	$	—			$	149
	5.67% senior unsecured notes due August 2014	—				408
	6.20% senior unsecured notes due April 2018	500				500
	6.75% senior unsecured notes due July 2018	150				150
	Variable-rate senior unsecured term loan due November 2018	300				—
	8.00% senior unsecured notes due October 2019	500				500
	5.65% senior unsecured notes due March 2020	300				300
	3.30% senior unsecured notes due March 2023	650				650
	6.75% senior unsecured notes due February 2032	240				240
	7.50% senior unsecured notes due September 2038	250				250
	Total Spectra Energy Capital, LLC Debt	2,890				3,147
	SEP
	SEP 2.95% senior unsecured notes due June 2016	250				250
	SEP 2.95% senior unsecured notes due September 2018	500				500
	SEP Variable-rate senior unsecured term loan due November 2018	400				400
	SEP 4.60% senior unsecured notes due June 2021	250				250
	SEP 4.75% senior unsecured notes due March 2024	1,000				1,000
	SEP 5.95% senior unsecured notes due September 2043	400				400
	Texas Eastern 6.00% senior unsecured notes due September 2017	400				400
	Texas Eastern 4.13% senior unsecured notes due December 2020	300				300
	Texas Eastern 2.80% senior unsecured notes due October 2022	500				500
	Texas Eastern 7.00% senior unsecured notes due July 2032	450				450
	Algonquin 3.51% senior notes due July 2024	350				350
	East Tennessee Natural Gas, LLC 3.10% senior notes due December 2024	200				200
	M&N U.S. 7.50% senior notes due May 2014	—				411
	Express-Platte 6.09% senior secured notes due January 2020	110				110
	Express-Platte 7.39% subordinated secured notes due 2014 to 2019	74				104
	Total SEP Debt	5,184				5,625
	Westcoast
	8.50% debentures due November 2015	108				118
	3.28% medium-term notes due January 2016	215				235
	8.50% debentures due September 2018	129				141
	5.60% medium-term notes due January 2019	258				282
	9.90% debentures due January 2020	86				94
	4.57% medium-term notes due July 2020	215				235
	3.88% medium-term notes due October 2021	129				142
	3.12% medium-term notes due December 2022	215				235
	3.43% medium-term notes due September 2024	301				—
	8.85% debentures due July 2025	129				142
	8.80% medium-term notes due November 2025	22				24
	7.30% debentures due December 2026	108				118
	6.75% medium-term notes due December 2027	129				141
	7.15% medium-term notes due March 2031	172				188
	4.79% medium-term notes due October 2041	129				141
	M&N Canada 6.90% senior secured notes due 2014 to 2019	112				147
	M&N Canada 4.34% senior secured notes due 2014 to 2019	83				120
	Other	2				2
	Total Westcoast Debt	$	2,542			$	2,505
		December 31,
		2014				2013
	Union Gas	(in millions)
	7.90% debentures due February 2014	$	—			$	141
	11.50% debentures due August 2015	129				141
	4.64% medium-term notes due June 2016	172				188
	9.70% debentures due November 2017	108				118
	5.35% medium-term notes due April 2018	172				188
	8.75% debentures due August 2018	108				118
	8.65% senior debentures due October 2018	64				72
	2.76% medium-term notes due June 2021	172				—
	4.85% medium-term notes due April 2022	108				118
3.79% medium-term notes due July 2023	215				235
8.65% debentures due November 2025	108				118
5.46% medium-term notes due September 2036	142				155
6.05% medium-term notes due September 2038	258				282
5.20% medium-term notes due July 2040	215				235
4.88% medium-term notes due June 2041	258				282
4.20% medium-term notes due June 2044	215				—
Total Union Gas Debt	2,444				2,391
Total
Long-term debt principal (including current maturities)	13,060				13,668
Change in fair value of debt hedged	17				17
Unamortized debt discount, net	(12		)		(12		)
Other unamortized items	7				12
Total other non-principal amounts	12				17
Commercial paper (a)	1,583				1,032
Capital Leases	24				—
Total debt (including capital lease obligations) (b)	14,679				14,717
Current maturities of long-term debt	(327		)		(1,197		)
Commercial paper (c)	(1,583		)		(1,032		)
Total long-term debt (including capital lease obligations)	$	12,769			$	12,488
______
(a)	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
(b)	As of December 31, 2014 and 2013, respectively, $5,264 million and $5,248 million of debt was denominated in Canadian dollars.
(c)	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.
Annual Maturities
	Annual Maturities	31-Dec-14
		(in millions)
	2015	$	327
	2016	713
	2017	563
	2018	2,353
	2019	787
	Thereafter	8,353
	Total long-term debt, including current maturities (a)	$	13,096
	______
	(a)	Excludes commercial paper of $1,583 million. Includes capital leases of $24 million and other non-principal amounts of $12 million.
Available Credit Facilities and Restrictive Debt Covenants	Available Credit Facilities and Restrictive Debt Covenants
		Expiration		Total				Commercial Paper Outstanding at December 31, 2014		Available
		Date		Credit						Credit
				Facilities						Facilities
				Capacity						Capacity
				(in millions)
	Spectra Energy Capital, LLC (a)	2019		$	1,000			$	398	$	602
	SEP (b)	2019		2,000				907		1,093
	Westcoast (c)	2019		344				46		298
	Union Gas (d)	2019		430				232		198
	Total			$	3,774			$	1,583	$	2,191
	______
	(a)	Revolving credit facility contains a covenant requiring the Spectra Energy Corp consolidated debt-to-total capitalization ratio, as defined in the agreement, to not exceed 65%. Per the terms of the agreement, collateralized debt is excluded from the calculation of the ratio. This ratio was 58% at December 31, 2014.
	(b)	Revolving credit facility contains a covenant that requires SEP to maintain a ratio of total Consolidated Indebtedness-to-Consolidated EBITDA, as defined in the agreement, of 5.0 to 1 or less. As of December 31, 2014, this ratio was 3.7 to 1.
	(c)	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 400 million Canadian dollars and contains a covenant that requires the Westcoast non-consolidated debt-to-total capitalization ratio to not exceed 75%. The ratio was 35% at December 31, 2014.
	(d)	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 500 million Canadian dollars and contains a covenant that requires the Union Gas debt-to-total capitalization ratio to not exceed 75% and a provision which requires Union Gas to repay all borrowings under the facility for a period of two days during the second quarter of each year. The ratio was 68% at December 31, 2014.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis with Fair Value Hierarchy Levels	The following presents, for each of the fair value hierarchy levels, assets and liabilities that are measured and recorded at fair value on a recurring basis:
	Description		31-Dec-14
		Consolidated Balance Sheet Caption	Total			Level 1			Level 2			Level 3
			(in millions)
	Corporate debt securities	Cash and cash equivalents	$	85		$	—		$	85		$	—
	Corporate debt securities	Current assets — other	3			—			3			—
	Commodity derivatives	Current assets — other	57			—			—			57
	Interest rate swaps	Current assets — other	2			—			2			—
	Commodity derivatives	Investments and other assets — other	21			—			—			21
	Corporate debt securities	Investments and other assets — other	20			—			20			—
	Interest rate swaps	Investments and other assets — other	22			—			22			—
	Money market funds	Investments and other assets — other	1			1			—			—
	Total Assets		$	211		$	1		$	132		$	78
	Description	Consolidated Balance Sheet Caption	31-Dec-13
			Total			Level 1			Level 2			Level 3
			(in millions)
	Corporate debt securities	Cash and cash equivalents	$	49		$	—		$	49		$	—
	Corporate debt securities	Current assets — other	7			—			7			—
	Interest rate swaps	Current assets — other	8			—			8			—
	Corporate debt securities	Investments and other assets — other	11			—			11			—
	Interest rate swaps	Investments and other assets — other	15			—			15			—
	Money market funds	Investments and other assets — other	1			1			—			—
	Total Assets		$	91		$	1		$	90		$	—
	Natural gas purchase contracts	Deferred credits and other liabilities —     regulatory and other	$	3		$	—		$	—		$	3
	Interest rate swaps	Deferred credits and other liabilities —     regulatory and other	6			—			6			—
	Total Liabilities		$	9		$	—		$	6		$	3
Changes in Level 3 Assets and Liabilities that are Measured at Fair Value on a Recurring Basis using Significant Unobservable Inputs	The following presents changes in Level 3 assets and liabilities that are measured at fair value on a recurring basis using significant unobservable inputs:
		2014			2013
		(in millions)
	Derivative assets (liabilities)
	Fair value, beginning of period	$	(3	)	$	(9	)
	Total gains (losses):
	Included in earnings	91			(3		)
	Included in other comprehensive income	5			8
	Settlements	(15		)	1
	Fair value, end of period	$	78		$	(3	)
	Total gains (losses) for the period included in earnings (or changes in net assets) attributable to the change in unrealized gains or losses relating to assets and liabilities held at the end of the period	$	56		$	(2	)
Fair Value of Financial Instruments Recorded and Carried at Book Value	Our AFS securities are classified on the Consolidated Balance Sheets as follows:
			Estimated Fair Value
			December 31,
			2014			2013
			(in millions)
	Restricted funds
	Investments and other assets—other		$	1		$	1
	Non-restricted funds
	Current assets—other		3			7
	Investments and other assets—other		20			11
	Total available-for-sale securities		$	24		$	19
	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.
		December 31,
		2014						2013
		Book			Approximate			Book			Approximate
		Value			Fair Value			Value			Fair Value
		(in millions)
	Note receivable, noncurrent (a)	$	71		$	71		$	71		$	71
	Long-term debt, including current maturities (b)	13,060			14,446			13,668			14,701
	__________
	(a)	Included within Investments in and Loans to Unconsolidated Affiliates.
	(b)	Excludes capital leases, unamortized items and fair value hedge carrying value adjustments.

Risk_Management_and_Hedging_Ac1

Risk Management and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Portfolio Carrying Value	Derivative Portfolio Carrying Value as of December 31, 2014
		Maturities			Maturities			Maturities			Maturities		Total
		in 2015			in 2016			in 2017			in 2018		Carrying
											and		Value
											Thereafter
		(in millions)
	Derivatives designated as hedging instruments
	Interest rate swaps	$	—		$	—		$	2		$	20	$	22
	Total derivatives designated as hedging instruments	—			—			2			20		22
	Derivatives not designated as hedging instruments
	Commodity derivatives	57			19			2			—		78
	Interest rate swaps	2			—			—			—		2
	Total derivatives not designated as hedging instruments	59			19			2			—		80
	Total derivative instruments	$	59		$	19		$	4		$	20	$	102
Commodity Derivative Assets and Liabilities Offsetting Table	Information about our commodity derivatives that had netting or rights of offset arrangements are as follows:
		31-Dec-14
		Gross			Gross			Net Amount Presented in the Condensed Consolidated Balance Sheets
		Amounts			Amounts
					Offset
	Description	(in millions)
	Assets	$	169		$	91		$	78
	Liabilities	91			91			—
Commodity derivative impact	Information regarding the impacts of commodity derivatives on our Consolidated Statements of Operations is as follows:
	Derivatives		Consolidated Statement of Operations Caption	2014			2013			2012
				(in millions)
	Commodity derivatives		Sales of natural gas liquids	$	93		$	—		$	—
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	Information about our interest rate swaps that had netting or rights of offset arrangements are as follows:
		31-Dec-14									31-Dec-13
		Gross Amounts			Amounts Not			Net			Gross Amounts		Amounts Not		Net
		Presented in			Offset in the			Amount			Presented in		Offset in the		Amount
		the Consolidated			Consolidated						the Consolidated		Consolidated
		Balance Sheets			Balance Sheets						Balance Sheets		Balance Sheets
	Description	(in millions)
	Assets	$	24		$	—		$	24		$	23	$	3	$	20
	Liabilities	—			—			—			6		3		3

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Summary of Future Minimum Lease Payments Under Operating Leases	The following is a summary of future minimum lease payments under operating leases which at inception had noncancelable terms of more than one year. We had no material capital lease commitments at December 31, 2014.
		Long-term
		Operating
		Leases
		(in millions)
	2015	$	50
	2016	44
	2017	42
	2018	36
	2019	32
	Thereafter	148
	Total future minimum lease payments	$	352

Effects_of_Changes_in_Noncontr1

Effects of Changes in Noncontrolling Interests Ownership (Tables)	12 Months Ended
	Dec. 31, 2014
Noncontrolling Interest [Abstract]
Effects of Changes in Ownership Interests in Non-Wholly Owned Consolidated Subsidiaries	The following table presents the effects of changes in our ownership interests in non-100%-owned consolidated subsidiaries:
		2014		2013		2012
		(in millions)
	Net income — controlling interests	$	1,082	$	1,038	$	940
	Increase in additional paid-in capital resulting from issuances of SEP units (a)	49		42		26
	Total net income — controlling interests and changes in equity — controlling interests	$	1,131	$	1,080	$	966
	________________
	(a)	See Note 2 for further discussion.

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Components of Pre-Tax Stock Based Compensation Expense in Continuing Operations	We recorded pre-tax stock-based compensation expense in continuing operations as follows, the components of which are described further below:
		2014				2013			2012
		(in millions)
	Phantom awards	$	14			$	13		$	12
	Performance awards	13				33			17
	Total	$	27			$	46		$	29
Stock Awards Activity	Stock Awards Activity
		Performance						Phantom Stock
		Awards						Awards
		Units			Weighted			Units			Weighted
					Average						Average
					Grant						Grant
					Date Fair						Date Fair
					Value						Value
		(thousands)						(thousands)
	Outstanding at December 31, 2013	1,936			$	38		1,302			$	29
	Granted	557			46			454			38
	Vested	(601	)		33			(431	)		26
	Forfeited	(117	)		38			(44	)		33
	Outstanding at December 31, 2014	1,775			35			1,281			33
	Awards expected to vest	1,709			35			1,229			33
Stock Option Activity	Stock Option Activity
		Options			Weighted-			Weighted-		Aggregate
					Average			Average		Intrinsic
					Exercise			Remaining		Value
					Price			Life
		(in thousands)						(in years)		(in millions)
	Outstanding at December 31, 2013	1,532			$	25		2.9		$	16
	Exercised	(430	)		25
	Forfeited or expired	—			—
	Outstanding at December 31, 2014	1,102			25			2		12
	Exercisable at December 31, 2014	1,102			25			2		12
Performance awards
Weighted Average Assumptions	Weighted-Average Assumptions for Stock-Based Performance Awards
		2014		2013		2012
	Risk-free rate of return	0.70%		0.40%		0.40%
	Expected life	3 years		3 years		3 years
	Expected volatility—Spectra Energy	20%		21%		25%
	Expected volatility—peer group	14%–32%		13%–33%		16%–42%
	Market index (a)	N/A		16%		20%

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Change in Projected Benefit Obligation and Change in Fair Value of Plan Assets	Change in Projected Benefit Obligation and Change in Fair Value of Plan Assets
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Change in Projected Benefit Obligation
	Projected benefit obligation, beginning of period	$	575			$	610			$	1,131		$	1,262
	Transfers in	—				—				—			6
	Service cost	19				19				25			33
	Interest cost	24				21				52			50
	Actuarial loss (gain)	13				(36		)		143			(92		)
	Participant contributions	—				—				5			5
	Benefits paid	(45		)		(39		)		(49		)	(51		)
	Foreign currency translation effect	—				—				(105		)	(82		)
	Projected benefit obligation, end of period	586				575				1,202			1,131
	Change in Fair Value of Plan Assets
	Plan assets, beginning of period	531				483				1,040			961
	Transfers in	—				—				—			3
	Actual return on plan assets	44				65				115			110
	Benefits paid	(45		)		(39		)		(49		)	(51		)
	Employer contributions	21				22				36			80
	Plan participants’ contributions	—				—				5			5
	Expected non-investment expenses	—				—				(3		)	—
	Foreign currency translation effect	—				—				(94		)	(68		)
	Plan assets, end of period	551				531				1,050			1,040
	Net amount recognized	$	(35	)		$	(44	)		$	(152	)	$	(91	)
	Accumulated Benefit Obligation	$	567			$	547			$	1,123		$	1,059
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Net amount recognized
	Current Liabilities - Other	$	(2	)		$	(2	)		$	(6	)	$	(6	)
	Deferred Credits and Other Liabilities -	(33		)		(42		)		(165		)	(130		)
	Regulatory and Other
	Other Assets - Other	—				—				19			45
	Total net amount recognized	$	(35	)		$	(44	)		$	(152	)	$	(91	)
Amounts Recognized in Accumulated Other Comprehensive Income	Amounts Recognized in Accumulated Other Comprehensive Income
		U.S.								Canada
		December 31,								December 31,
		2014				2013				2014			2013
		(in millions)
	Net actuarial loss	$	141			$	145			$	345		$	275
	Prior service cost	—				1				6			7
	Total amount recognized in AOCI	$	141			$	146			$	351		$	282
Components of Net Periodic Cost	Components of Net Periodic Pension Costs
		U.S.											Canada
		2014				2013				2012			2014				2013			2012
		(in millions)
	Net Periodic Pension Cost
	Service cost benefit earned	$	19			$	19			$	17		$	29			$	33		$	30
	Interest cost on projected benefit obligation	24				21				23			52				50			50
	Expected return on plan assets	(39		)		(33		)		(33		)	(69		)		(66		)	(61		)
	Amortization of prior service cost	—				—				—			2				2			2
	Amortization of loss	13				20				15			22				35			36
	Net periodic pension cost	17				27				22			36				54			57
	Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
	Current year actuarial loss (gain)	8				(69		)		33			93				(133		)	44
	Amortization of actuarial loss	(13		)		(20		)		(15		)	(22		)		(35		)	(36		)
	Amortization of prior service credit	—				—				—			(2		)		(2		)	(2		)
	Total recognized in other comprehensive income	(5		)		(89		)		18			69				(170		)	6
	Total Recognized in Net Periodic Pension Cost and Other Comprehensive Income	$	12			$	(62	)		$	40		$	105			$	(116	)	$	63
Assumptions Used for Benefits Accounting	Assumptions Used for Pension Benefits Accounting
		U.S.									Canada
		2014			2013			2012			2014		2013			2012
	Benefit Obligations
	Discount rate	4.1	%		4.31	%		3.55	%		4	%	4.81	%		4.15	%
	Salary increase	4			4.61			4.61			3.25		3.25			3.25
	Net Periodic Benefit Cost
	Discount rate	4.31			3.55			4.17			4.81		4.15			4.3
	Salary increase	4.61			4.61			4.61			3.25		3.25			3.25
	Expected long-term rate of return on plan assets	8			7.4			7.4			7.4		7.1			7.1
Assumed Health Care Cost Trend Rates	Assumed Health Care Cost Trend Rates
		U.S.				Canada
		2014		2013		2014		2013
	Health care cost trend rate assumed for next year	7.00%		7.00%		6.00%		6.50%
	Rate to which the cost trend is assumed to decline	5.00%		5.00%		5.00%		5.00%
	Year that the rate reaches the ultimate trend rate	2019		2019		2017		2017
Sensitivity to Changes in Assumed Health Care Cost Trend Rates	Sensitivity to Changes in Assumed Health Care Cost Trend Rates
		U.S.								Canada
		1% Point				1% Point				1% Point			1% Point
		Increase				Decrease				Increase			Decrease
		(in millions)
	Effect on total service and interest costs	$	—			$	—			$	1		$	(1	)
	Effect on post-retirement benefit obligations	7				(6		)		9			(7		)
Qualified pension plans
Changes in Level 3 Assets That are Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs	The following presents changes in Level 3 assets that are measured at fair value on a recurring basis using significant unobservable inputs:
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Fair value, beginning of period	$	49			$	69			$	—		$	1
	Sales	—				(25		)		—			—
	Settlements	—				1				—			—
	Gain (loss) included in other comprehensive income	4				4				—			(1		)
	Fair value, end of period	$	53			$	49			$	—		$	—
Pension Plans, Defined Benefit | Qualified pension plans
Target Allocation of Plan Assets	Qualified Pension Plan Assets
		U.S.									Canada
	Asset Category	Target			December 31,						Target		December 31,
		Allocation			2014			2013			Allocation		2014			2013
	U.S. equity securities	30	%		31	%		31	%		17	%	17	%		18	%
	Canadian equity securities	—			—			—			25		25			26
	Other equity securities	14			11			14			13		13			13
	Fixed income securities	46			48			45			45		45			43
	Other investments	10			10			10			—		—			—
	Total	100	%		100	%		100	%		100	%	100	%		100	%
Fair Value of Plan Assets	The following table summarizes the fair values of pension plan assets recorded at each fair value hierarchy level, as determined in accordance with the valuation techniques described in Note 18:
		U.S.															Canada
		Total				Level 1				Level 2			Level 3				Total			Level 1			Level 2		Level 3
		(in millions)
	31-Dec-14
	Cash and cash equivalents	$	3			$	3			$	—		$	—			$	3		$	3		$	—	$	—
	Fixed income securities	262				262				—			—				471			471			—		—
	Equity securities	233				233				—			—				576			342			234		—
	Other	53				—				—			53				—			—			—		—
	Total	$	551			$	498			$	—		$	53			$	1,050		$	816		$	234	$	—
	31-Dec-13
	Cash and cash equivalents	$	2			$	2			$	—		$	—			$	8		$	8		$	—	$	—
	Fixed income securities	240				240				—			—				442			442			—		—
	Equity securities	240				240				—			—				590			428			162		—
	Other	49				—				—			49				—			—			—		—
	Total	$	531			$	482			$	—		$	49			$	1,040		$	878		$	162	$	—
Expected Benefit Payments	Expected Benefit Payments
		U.S.				Canada
		(in millions)
	2015	$	42			$	51
	2016	47				54
	2017	50				57
	2018	49				60
	2019	53				63
	2020 – 2024	235				346
U.S. and Canada Other Post-Retirement Benefits
Change in Projected Benefit Obligation and Change in Fair Value of Plan Assets	Other Post-Retirement Benefit Plans — Change in Projected Benefit Obligation and Fair Value of Plan Assets
		U.S.								Canada
		2014				2013				2014			2013
		(in millions)
	Change in Benefit Obligation
	Accumulated post-retirement benefit obligation, beginning of period	$	184			$	202			$	133		$	149
	Transfers in	—				—				—			1
	Service cost	1				1				4			5
	Interest cost	8				7				6			6
	Plan participants’ contributions	2				3				—			—
	Actuarial loss (gain)	(7		)		(13		)		7			(13		)
	Medicare subsidy receivable	2				2				—			—
	Benefits paid	(18		)		(18		)		(4		)	(5		)
	Foreign currency translation effect	—				—				(13		)	(10		)
	Accumulated post-retirement benefit obligation, end of period	172				184				133			133
	Change in Fair Value of Plan Assets
	Plan assets, beginning of period	87				79				—			—
	Actual return on plan assets	7				10				—			—
	Benefits paid	(18		)		(18		)		(4		)	(5		)
	Employer contributions	14				13				4			5
	Plan participants’ contributions	2				3				—			—
	Plan assets, end of period	92				87				—			—
	Net amount recognized (a)	$	(80	)		$	(97	)		$	(133	)	$	(133	)
	_______
	(a)	Recognized primarily in Deferred Credits and Other Liabilities—Regulatory and Other in the Consolidated Balance Sheets.
Amounts Recognized in Accumulated Other Comprehensive Income	Other Post-Retirement Benefit Plans — Amounts Recognized in Accumulated Other Comprehensive Income
		U.S.								Canada
		December 31,								December 31,
		2014				2013				2014			2013
		(in millions)
	Prior service credit	$	—			$	—			$	(4	)	$	(5	)
	Net actuarial loss (gain)	(4		)		6				12			6
	Total amount recognized in AOCI	$	(4	)		$	6			$	8		$	1
Components of Net Periodic Cost
		U.S.											Canada
		2014				2013				2012			2014				2013			2012
		(in millions)
	Other Post-Retirement Benefit Plans — Components of Net Periodic Benefit Cost
	Service cost benefit earned	$	1			$	1			$	1		$	4			$	5		$	7
	Interest cost on accumulated post-retirement benefit obligation	8				7				8			6				6			7
	Expected return on plan assets	(5		)		(4		)		(5		)	—				—			—
	Amortization of prior service credit	—				—				—			(1		)		(1		)	(1		)
	Amortization of loss	1				2				2			—				—			2
	Net periodic other post-retirement benefit cost	5				6				6			9				10			15
	Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
	Current year actuarial loss (gain)	(9		)		(18		)		6			6				(13		)	(26		)
	Amortization of actuarial loss	(1		)		(2		)		(2		)	—				—			(2		)
	Amortization of prior service credit	—				—				—			1				1			1
	Total recognized in other comprehensive income	(10		)		(20		)		4			7				(12		)	(27		)
	Total recognized in net periodic benefit cost and other comprehensive income	$	(5	)		$	(14	)		$	10		$	16			$	(2	)	$	(12	)
Assumptions Used for Benefits Accounting	Other Post-Retirement Benefits Plans — Assumptions Used for Benefits Accounting
		U.S.									Canada
		2014			2013			2012			2014		2013			2012
	Benefit Obligations
	Discount rate	4.08	%		4.46	%		3.7	%		4	%	4.83	%		4.2	%
	Salary increase	4			4.61			4.61			3.25		3.25			3.25
	Net Periodic Benefit Cost
	Discount rate	4.46			3.7			4.31			4.83		4.2			4.33
	Salary increase	4.61			4.61			4.61			3.25		3.25			3.25
	Expected return on plan assets	6.98			6.51			6.54			N/A		N/A			N/A
	_________
Target Allocation of Plan Assets	Other Post-Retirement Plan Assets
		U.S.
	Asset Category	December 31,
		2014			2013
	Equity securities	48	%		49	%
	Fixed income securities	47			46
	Other assets	5			5
	Total	100	%		100	%
Fair Value of Plan Assets	The asset allocation table above includes the other post-retirement benefit assets held in the master trusts, VEBA I and VEBA II.
	The following table summarizes the fair values of the other post-retirement plan asse
Expected Benefit Payments	The following benefit payments and subsidies are expected to be paid (or received) over each of the next five years and thereafter.
		Benefit Payments								Medicare Part D Subsidy Receipts
		U.S.				Canada				U.S.
		(in millions)
	2015	$	16			$	5			$	(2	)
	2016	15				5				(2		)
	2017	15				5				(1		)
	2018	14				6				(1		)
	2019	14				6				(1		)
	2020 – 2024	60				33				(6		)
U.S.
Changes in Level 3 Assets That are Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs	The following presents changes in Level 3 assets that are measured at fair value on a recurring basis using significant unobservable inputs:
		U.S.
		2014				2013
		(in millions)
	Fair value, beginning of period	$	4			$	5
	Sales	—				(2		)
	Unrealized gain included in other comprehensive income	—				1
	Fair value, end of period	$	4			$	4

Consolidating_Financial_Inform1

Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Statement of Operations	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2014
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,906		$	(3	)	$	5,903
	Total operating expenses	6			1			3,975			(3		)	3,979
	Operating income (loss)	(6		)	(1		)	1,931			—			1,924
	Equity in earnings of unconsolidated affiliates	—			—			361			—			361
	Equity in earnings of consolidated subsidiaries	1,054			1,651			—			(2,705		)	—
	Other income and expenses, net	(2		)	9			52			—			59
	Interest expense	—			253			426			—			679
	Earnings before income taxes	1,046			1,406			1,918			(2,705		)	1,665
	Income tax expense (benefit)	(36		)	352			66			—			382
	Net income	1,082			1,054			1,852			(2,705		)	1,283
	Net income — noncontrolling interests	—			—			201			—			201
	Net income — controlling interests	$	1,082		$	1,054		$	1,651		$	(2,705	)	$	1,082
	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2013
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,521		$	(3	)	$	5,518
	Total operating expenses	8			3			3,844			(3		)	3,852
	Operating income (loss)	(8		)	(3		)	1,677			—			1,666
	Equity in earnings of unconsolidated affiliates	—			—			445			—			445
	Equity in earnings of consolidated subsidiaries	1,015			1,649			—			(2,664		)	—
	Other income and expenses, net	1			15			108			—			124
	Interest expense	—			216			441			—			657
	Earnings before income taxes	1,008			1,445			1,789			(2,664		)	1,578
	Income tax expense (benefit)	(30		)	430			19			—			419
	Net income	1,038			1,015			1,770			(2,664		)	1,159
	Net income — noncontrolling interests	—			—			121			—			121
	Net income — controlling interests	$	1,038		$	1,015		$	1,649		$	(2,664	)	$	1,038
	Spectra Energy Corp
	Condensed Consolidating Statement of Operations
	Year Ended December 31, 2012
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Total operating revenues	$	—		$	—		$	5,077		$	(2	)	$	5,075
	Total operating expenses	5			5			3,492			(2		)	3,500
	Operating income (loss)	(5		)	(5		)	1,585			—			1,575
	Equity in earnings of unconsolidated affiliates	—			—			382			—			382
	Equity in earnings of consolidated subsidiaries	917			1,377			—			(2,294		)	—
	Other income and expenses, net	(2		)	3			82			—			83
	Interest expense	—			190			435			—			625
	Earnings from continuing operations before income taxes	910			1,185			1,614			(2,294		)	1,415
	Income tax expense (benefit) from continuing operations	(31		)	268			133			—			370
	Income from continuing operations	941			917			1,481			(2,294		)	1,045
	Income (loss) from discontinued operations, net of tax	(1		)	—			3			—			2
	Net income	940			917			1,484			(2,294		)	1,047
	Net income — noncontrolling interests	—			—			107			—			107
	Net income — controlling interests	$	940		$	917		$	1,377		$	(2,294	)	$	940
Condensed Consolidating Statement of Comprehensive Income	Spectra Energy Corp
	Condensed Consolidating Statements of Comprehensive Income
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Year Ended December 31, 2014
	Net income	$	1,082		$	1,054		$	1,852		$	(2,705	)	$	1,283
	Other comprehensive income (loss)	9			1			(596		)	—			(586		)
	Total comprehensive income, net of tax	1,091			1,055			1,256			(2,705		)	697
	Less: comprehensive income — noncontrolling interests	—			—			194			—			194
	Comprehensive income — controlling interests	$	1,091		$	1,055		$	1,062		$	(2,705	)	$	503
	Year Ended December 31, 2013
	Net income	$	1,038		$	1,015		$	1,770		$	(2,664	)	$	1,159
	Other comprehensive income (loss)	69			2			(346		)	—			(275		)
	Total comprehensive income, net of tax	1,107			1,017			1,424			(2,664		)	884
	Less: comprehensive income — noncontrolling interests	—			—			114			—			114
	Comprehensive income — controlling interests	$	1,107		$	1,017		$	1,310		$	(2,664	)	$	770
	Year Ended December 31, 2012
	Net income	$	940		$	917		$	1,484		$	(2,294	)	$	1,047
	Other comprehensive income (loss)	(12		)	3			248			—			239
	Total comprehensive income, net of tax	928			920			1,732			(2,294		)	1,286
	Less: comprehensive income — noncontrolling interests	—			—			110			—			110
	Comprehensive income — controlling interests	$	928		$	920		$	1,622		$	(2,294	)	$	1,176
Condensed Consolidating Balance Sheet	Spectra Energy Corp
	Condensed Consolidating Balance Sheet
	December 31, 2014
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Cash and cash equivalents	$	—		$	1		$	214		$	—		$	215
	Receivables — consolidated subsidiaries	18			—			11			(29		)	—
	Receivables — other	2			—			1,334			—			1,336
	Other current assets	71			2			708			—			781
	Total current assets	91			3			2,267			(29		)	2,332
	Investments in and loans to unconsolidated affiliates	—			—			2,966			—			2,966
	Investments in consolidated subsidiaries	14,531			20,562			—			(35,093		)	—
	Advances receivable — consolidated subsidiaries	—			4,683			898			(5,581		)	—
	Notes receivable — consolidated subsidiaries	—			—			3,198			(3,198		)	—
	Goodwill	—			—			4,714			—			4,714
	Other assets	38			22			267			—			327
	Net property, plant and equipment	—			—			22,307			—			22,307
	Regulatory assets and deferred debits	4			15			1,375			—			1,394
	Total Assets	$	14,664		$	25,285		$	37,992		$	(43,901	)	$	34,040
	Accounts payable	$	3		$	—		$	455		$	—		$	458
	Accounts payable — consolidated subsidiaries	—			17			12			(29		)	—
	Commercial paper	—			398			1,185			—			1,583
	Short-term borrowings — consolidated subsidiaries	—			398			—			(398		)	—
	Taxes accrued	5			—			86			—			91
	Current maturities of long-term debt	—			—			327			—			327
	Other current liabilities	96			54			1,200			—			1,350
	Total current liabilities	104			867			3,265			(427		)	3,809
	Long-term debt	—			2,900			9,869			—			12,769
	Advances payable — consolidated subsidiaries	5,581			—			—			(5,581		)	—
	Notes payable — consolidated subsidiaries	—			2,800			—			(2,800		)	—
	Deferred credits and other liabilities	819			4,187			1,800			—			6,806
	Preferred stock of subsidiaries	—			—			258			—			258
	Equity
	Controlling interests	8,160			14,531			20,562			(35,093		)	8,160
	Noncontrolling interests	—			—			2,238			—			2,238
	Total equity	8,160			14,531			22,800			(35,093		)	10,398
	Total Liabilities and Equity	$	14,664		$	25,285		$	37,992		$	(43,901	)	$	34,040
	Spectra Energy Corp
	Condensed Consolidating Balance Sheet
	December 31, 2013
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	Cash and cash equivalents	$	—		$	12		$	189		$	—		$	201
	Receivables — consolidated subsidiaries	176			394			—			(570		)	—
	Receivables — other	1			—			1,335			—			1,336
	Other current assets	40			15			489			—			544
	Total current assets	217			421			2,013			(570		)	2,081
	Investments in and loans to unconsolidated affiliates	—			—			3,043			—			3,043
	Investments in consolidated subsidiaries	13,244			19,403			—			(32,647		)	—
	Advances receivable — consolidated subsidiaries	—			4,038			677			(4,715		)	—
	Notes receivable — consolidated subsidiaries	—			—			3,215			(3,215		)	—
	Goodwill	—			—			4,810			—			4,810
	Other assets	39			30			316			—			385
	Net property, plant and equipment	—			—			21,829			—			21,829
	Regulatory assets and deferred debits	3			17			1,365			—			1,385
	Total Assets	$	13,503		$	23,909		$	37,268		$	(41,147	)	$	33,533
	Accounts payable	$	4		$	—		$	436		$	—		$	440
	Accounts payable — consolidated subsidiaries	89			—			481			(570		)	—
	Commercial paper	—			344			688			—			1,032
	Short-term borrowings — consolidated subsidiaries	—			415			—			(415		)	—
Taxes accrued	4			—			68			—			72
Current maturities of long-term debt	—			557			640			—			1,197
Other current liabilities	81			75			1,142			—			1,298
Total current liabilities	178			1,391			3,455			(985		)	4,039
Long-term debt	—			2,605			9,883			—			12,488
Advances payable — consolidated subsidiaries	4,715			—			—			(4,715		)	—
Notes payable — consolidated subsidiaries	—			2,800			—			(2,800		)	—
Deferred credits and other liabilities	116			3,869			2,440			—			6,425
Preferred stock of subsidiaries	—			—			258			—			258
Equity
Controlling interests	8,494			13,244			19,403			(32,647		)	8,494
Noncontrolling interests	—			—			1,829			—			1,829
Total equity	8,494			13,244			21,232			(32,647		)	10,323
Total Liabilities and Equity	$	13,503		$	23,909		$	37,268		$	(41,147	)	$	33,533
Condensed Consolidating Statement of Cash Flows	Spectra Energy Corp
	Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2014
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital			Subsidiaries
		Corp
	CASH FLOWS FROM OPERATING ACTIVITIES
	Net income	$	1,082		$	1,054		$	1,852		$	(2,705	)	$	1,283
	Adjustments to reconcile net income to net cash provided by (used in) operating activities:
	Depreciation and amortization	—			—			809			—			809
	Equity in earnings of unconsolidated affiliates	—			—			(361		)	—			(361		)
	Equity in earnings of consolidated subsidiaries	(1,054		)	(1,651		)	—			2,705			—
	Distributions received from unconsolidated affiliates	—			—			380			—			380
	Other	14			304			(208		)	—			110
	Net cash provided by (used in) operating activities	42			(293		)	2,472			—			2,221
	CASH FLOWS FROM INVESTING ACTIVITIES
	Capital expenditures	—			—			(2,028		)	—			(2,028		)
	Investments in and loans to unconsolidated affiliates	—			—			(259		)	—			(259		)
	Purchases of held-to-maturity securities	—			—			(790		)	—			(790		)
	Proceeds from sales and maturities of held-to-maturity securities	—			—			815			—			815
	Purchases of available-for-sale securities	—			—			(13		)	—			(13		)
	Proceeds from sales and maturities of available-for-sale securities	—			—			7			—			7
	Distributions received from unconsolidated affiliates	—			—			266			—			266
	Advances from affiliates	92			495			—			(587		)	—
	Other changes in restricted funds	—			—			(1		)	—			(1		)
	Net cash provided by (used in) investing activities	92			495			(2,003		)	(587		)	(2,003		)
	CASH FLOWS FROM FINANCING ACTIVITIES
	Proceeds from the issuance of long-term debt	—			300			728			—			1,028
	Payments for the redemption of long-term debt	—			(557		)	(627		)	—			(1,184		)
	Net increase in commercial paper	—			54			520			—			574
	Distributions to noncontrolling interests	—			—			(175		)	—			(175		)
	Contributions from noncontrolling interests	—			—			145			—			145
	Proceeds from the issuance of SEP common units	—			—			327			—			327
	Dividends paid on common stock	(925		)	—			—			—			(925		)
	Distributions and advances from (to) affiliates	777			(10		)	(1,354		)	587			—
	Other	14			—			(3		)	—			11
	Net cash used in financing activities	(134		)	(213		)	(439		)	587			(199		)
	Effect of exchange rate changes on cash	—			—			(5		)	—			(5		)
	Net increase (decrease) in cash and cash equivalents	—			(11		)	25			—			14
	Cash and cash equivalents at beginning of period	—			12			189			—			201
	Cash and cash equivalents at end of period	$	—		$	1		$	214		$	—		$	215
	Spectra Energy Corp
	Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2013
	(In millions)
		Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
		Energy			Capital (a)			Subsidiaries (a)
		Corp
	CASH FLOWS FROM OPERATING ACTIVITIES
	Net income	$	1,038		$	1,015		$	1,770		$	(2,664	)	$	1,159
	Adjustments to reconcile net income to net cash provided by (used in) operating activities:
	Depreciation and amortization	—			—			787			—			787
	Equity in earnings of unconsolidated affiliates	—			—			(445		)	—			(445		)
	Equity in earnings of consolidated subsidiaries	(1,015		)	(1,649		)	—			2,664			—
	Distributions received from unconsolidated affiliates	—			—			324			—			324
	Other	(2		)	478			(271		)	—			205
	Net cash provided by (used in) operating activities	21			(156		)	2,165			—			2,030
	CASH FLOWS FROM INVESTING ACTIVITIES
	Capital expenditures	—			—			(1,947		)	—			(1,947		)
	Investments in and loans to unconsolidated affiliates	—			—			(312		)	—			(312		)
	Acquisitions, net of cash acquired	—			—			(1,254		)	—			(1,254		)
	Purchases of held-to-maturity securities	—			—			(985		)	—			(985		)
	Proceeds from sales and maturities of held-to-maturity securities	—			—			1,023			—			1,023
Purchases of available-for-sale securities	—			—			(5,878		)	—			(5,878		)
Proceeds from sales and maturities of available-for-sale securities	—			—			6,024			—			6,024
Distributions received from unconsolidated affiliates	—			—			87			—			87
Advances to affiliates	(75		)	(1,856		)	—			1,931			—
Loan to unconsolidated affiliate	—			—			(71		)	—			(71		)
Repayment of loan to unconsolidated affiliate	—			71			—			—			71
Other changes in restricted funds	—			—			2			—			2
Other	—			—			4			—			4
Net cash used in investing activities	(75		)	(1,785		)	(3,307		)	1,931			(3,236		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			1,848			2,524			—			4,372
Payments for the redemption of long-term debt	—			(1,944		)	(195		)	—			(2,139		)
Net decrease in commercial paper	—			(170		)	(36		)	—			(206		)
Net increase in short-term borrowings – consolidated subsidiaries	—			(497		)	—			497			—
Distributions to noncontrolling interests	—			—			(144		)	—			(144		)
Contributions from noncontrolling interests	—			—			23			—			23
Proceeds from the issuance of SEP common units	—			—			214			—			214
Dividends paid on common stock	(821		)	—			—			—			(821		)
Distributions and advances from (to) affiliates	847			2,718			(1,137		)	(2,428		)	—
Other	28			(5		)	(6		)	—			17
Net cash provided by financing activities	54			1,950			1,243			(1,931		)	1,316
Effect of exchange rate changes on cash	—			—			(3		)	—			(3		)
Net increase in cash and cash equivalents	—			9			98			—			107
Cash and cash equivalents at beginning of period	—			3			91			—			94
Cash and cash equivalents at end of period	$	—		$	12		$	189		$	—		$	201
____________
(a)	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
Spectra Energy Corp
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2012
(In millions)
	Spectra			Spectra			Non-Guarantor			Eliminations			Consolidated
	Energy			Capital			Subsidiaries
	Corp			(a)			(a)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	940		$	917		$	1,484		$	(2,294	)	$	1,047
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	—			—			760			—			760
Equity in earnings of unconsolidated affiliates	—			—			(382		)	—			(382		)
Equity in earnings of consolidated subsidiaries	(917		)	(1,377		)	—			2,294			—
Distributions received from unconsolidated affiliates	—			—			307			—			307
Other	(86		)	246			46			—			206
Net cash provided by (used in) operating activities	(63		)	(214		)	2,215			—			1,938
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	—			—			(2,025		)	—			(2,025		)
Investments in and loans to unconsolidated affiliates	—			—			(520		)	—			(520		)
Acquisitions, net of cash acquired	—			—			(30		)	—			(30		)
Purchases of held-to-maturity securities	—			—			(2,671		)	—			(2,671		)
Proceeds from sales and maturities of held-to-maturity securities	—			—			2,578			—			2,578
Purchases of available-for-sale securities	—			—			(644		)	—			(644		)
Proceeds from sales and maturities of available-for-sale securities	—			—			514			—			514
Distributions received from unconsolidated affiliates	—			—			17			—			17
Advances from (to) affiliates	(163		)	(335		)	888			(390		)	—
Other changes in restricted funds	—			—			93			—			93
Other	—			—			14			—			14
Net cash used in investing activities	(163		)	(335		)	(1,786		)	(390		)	(2,674		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			—			1,301			—			1,301
Payments for the redemption of long-term debt	—			—			(525		)	—			(525		)
Net increase (decrease) in commercial paper	—			(238		)	437			—			199
Net increase in short-term borrowings - consolidated subsidiaries	—			322			—			(322		)	—
Distributions to noncontrolling interests	—			—			(120		)	—			(120		)
Proceeds from the issuance of Spectra Energy common stock	382			—			—			—			382
Proceeds from the issuance of SEP common units	—			—			145			—			145
Dividends paid on common stock	(753		)	—			—			—			(753		)
Distributions and advances from (to) affiliates	564			466			(1,742		)	712			—
Other	33			—			(8		)	—			25
Net cash provided by (used in) financing activities	226			550			(512		)	390			654
Effect of exchange rate changes on cash	—			—			2			—			2
Net increase (decrease) in cash and cash equivalents	—			1			(81		)	—			(80		)
Cash and cash equivalents at beginning of period	—			2			172			—			174
Cash and cash equivalents at end of period	$	—		$	3		$	91		$	—		$	94

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data
		First		Second		Third		Fourth		Total
		Quarter		Quarter		Quarter		Quarter
		(in millions, except per share amounts)
	2014
	Operating revenues	$	1,843	$	1,253	$	1,207	$	1,600	$	5,903
	Operating income	639		338		382		565		1,924
	Net income	467		188		254		374		1,283
	Net income — controlling interests	419		146		201		316		1,082
	Earnings per share (a)
	Basic	0.63		0.22		0.3		0.47		1.61
	Diluted	0.62		0.22		0.3		0.47		1.61
	2013
	Operating revenues	$	1,589	$	1,220	$	1,144	$	1,565	$	5,518
	Operating income	506		354		333		473		1,666
	Net income	370		226		292		271		1,159
	Net income — controlling interests	340		199		263		236		1,038
	Earnings per share (a)
	Basic	0.51		0.3		0.39		0.35		1.55
	Diluted	0.51		0.3		0.39		0.35		1.55
	___________
	(a)	Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to rounding.

Summary_of_Operations_and_Sign2

Summary of Operations and Significant Accounting Policies (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Significant Accounting Policies [Line Items]
Percentage of consolidated revenues by customer	There were no customers accounting for 10% or more of consolidated revenues during 2014, 2013 or 2012.	There were no customers accounting for 10% or more of consolidated revenues during 2014, 2013 or 2012.	There were no customers accounting for 10% or more of consolidated revenues during 2014, 2013 or 2012.
Allowance for funds used during construction	$72	$155	$131
Equity component of allowance for funds used during construction	53	105	85
Interest expense component of allowance for funds used during construction	19	50	46
Receivables, net	1,336	1,336
Other	1,169	1,097
Maximum
Significant Accounting Policies [Line Items]
Revolving credit facility, terms	90 days
Natural Gas Imbalances
Significant Accounting Policies [Line Items]
Receivables, net	642	606
Other	634	575
Other Expense
Significant Accounting Policies [Line Items]
Foreign currency transaction gains (losses)	$3	$1	($3)
DCP Midstream, LLC
Significant Accounting Policies [Line Items]
Percentage of ownership	50.00%

Spectra_Energy_Partners_LP_Add

Spectra Energy Partners, LP - Additional Information (Detail) (USD $)	0 Months Ended	1 Months Ended	12 Months Ended			0 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Nov. 01, 2013	Apr. 30, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 03, 2014	Oct. 31, 2012	Aug. 31, 2013	Nov. 30, 2013	Aug. 05, 2013	Nov. 30, 2015
Related Party Transaction [Line Items]
Proceeds from Issuance or Sale of Equity		$190
Proceeds from the issuance of Spectra Energy Partners common units			327	214	145
Equity interest issued (in shares)	167,600,000
General partner units issued (in shares)	3,400,000
Payments to Acquire Businesses, Gross	2,300
Spectra Energy Partners
Related Party Transaction [Line Items]
Proceeds from Issuance or Sale of Equity		193
Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Partners' Capital Account, Units, Sale of Units			6,400,000	600,000
Proceeds from Issuance or Sale of Equity			327	24	148
Business Combination Recognized Identifiable Assets Acquired And Liabilities Assumed Non-current Liabilities Long Term Debt Including Current Portion	2,400
Percentage of ownership interests			82.00%
Partners' Capital Account, Sale of Units	733					29
Partners Capital Account Sale Of Units Net Of Tax	-458					-16
Noncontrolling Interest, Period Increase (Decrease)	733					29
General Partner | Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Partners' Capital Account, Units, Sale of Units		100,000			100,000
Percentage of ownership interests			2.00%
Limited Partner | Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Partners' Capital Account, Units, Sale of Units		5,200,000			5,500,000
Steckman Ridge LP
Related Party Transaction [Line Items]
Business Acquisition, Percentage of Voting Interests NOT acquired	1.00%
Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Equity interest issued (in shares)						4,300,000
General partner units issued (in shares)						86,000
Subsidiaries
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed										60.00%
Southeast Supply Header
Related Party Transaction [Line Items]
Business Acquisition, Percentage of Voting Interests NOT acquired	25.05%
Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Percentage of Voting Rights Maintained						2.00%
Spectra Energy Partners, LP | Steckman Ridge, LP
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed						1.00%
Spectra Energy Partners, LP | Southeast Supply Header
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed						24.95%
Scenario, Forecast | Spectra Energy Partners, LP | Southeast Supply Header
Related Party Transaction [Line Items]
Percentage of Voting Rights Not Acquired											0.10%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Bobcat
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			100.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Texas Eastern
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			100.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Southeast Supply Header
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			50.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Algonquin
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			100.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Maritimes Northeast Pipeline Llc
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			38.77%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Sand Hills and Southern Hills
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			33.30%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Gulfstream
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			1.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Market Hub Partners Holdings
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			50.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | Spectra Energy Partners, LP | Steckman Ridge LP
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			50.00%
At Least Twelve Months after the U.S. Assets Dropdown [Member] | United States | Spectra Energy Partners, LP | Express Platte Pipeline System
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed			60.00%
Maritimes Northeast Pipeline Llc | Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Business Combination, Consideration Transferred							375
Percentage of Voting Rights Contributed							38.76%
Payments to Acquire Businesses, Gross							319
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable							56
Express Platte Pipeline System
Related Party Transaction [Line Items]
Equity interest issued (in shares)								7,200,000
Partners' Capital Account, Sale of Units								84
Express Platte Pipeline System | Spectra Energy Partners
Related Party Transaction [Line Items]
Noncontrolling Interest, Period Increase (Decrease)								84
Express Platte Pipeline System | Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Payments to Acquire Businesses, Gross								410
Express Platte Pipeline System | Subsidiaries
Related Party Transaction [Line Items]
Partners Capital Account Sale Of Units Net Of Tax								-53
Express Platte Pipeline System | United States
Related Party Transaction [Line Items]
Percentage of Voting Rights Contributed								40.00%
Express Platte Pipeline System | Canada
Related Party Transaction [Line Items]
Percentage of voting rights sold								100.00%
Additional Paid-in Capital
Related Party Transaction [Line Items]
Partners' Capital Account, Sale of Units					42		54
Partners Capital Account Sale Of Units Net Of Tax				38	26		34
Additional Paid-in Capital | Spectra Energy Partners
Related Party Transaction [Line Items]
Partners' Capital Account, Sale of Units				61
Noncontrolling Interests
Related Party Transaction [Line Items]
Noncontrolling Interest, Increase from Subsidiary Equity Issuance				128	108
Noncontrolling Interest, Period Increase (Decrease)							-54
Maximum | Spectra Energy Partners, LP
Related Party Transaction [Line Items]
Proceeds from Issuance or Sale of Equity									$400

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions - Additional Information (Detail) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Nov. 01, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 14, 2013	Mar. 31, 2013	Nov. 30, 2012	Mar. 31, 2014
Business Acquisition [Line Items]
Acquisitions, net of cash acquired		$0	$1,254	$30
Goodwill		4,714	4,810	4,513
Cash purchase price	2,300
Express Platte
Business Acquisition [Line Items]
Percentage of ownership interests acquired					100.00%
Business combination, consideration transferred					1,500
Acquisitions, net of cash acquired						1,254
Long-term debt acquired					260
Property, plant and equipment					1,251
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other					9
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other					259
Goodwill					523
Cash purchase price					1,250
Sand Hills and Southern Hills
Business Acquisition [Line Items]
Percentage of ownership interests acquired		33.00%
Cash purchase price			459				459
Subsidiary Issuer | United States | Express Platte
Business Acquisition [Line Items]
Percentage of Voting Rights Contributed		100.00%
Subsidiary Issuer | Canada | Express Platte
Business Acquisition [Line Items]
Percentage of voting rights sold		100.00%
Change in Approximate Fair Value | Express Platte
Business Acquisition [Line Items]
Property, plant and equipment								60
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other								1
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other								24
Goodwill								$37

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions - Summary of Fair Values of Assets and Liabilities Acquired (Detail) (USD $)	0 Months Ended
In Millions, unless otherwise specified	Nov. 01, 2013	Mar. 14, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Business Acquisition [Line Items]
Cash purchase price	$2,300
Goodwill			4,714	4,810	4,513
Express-Platte
Business Acquisition [Line Items]
Cash purchase price		1,250
Working capital and other purchase adjustments		71
Total		1,321
Cash		67
Receivables		25
Other current assets		9
Property, plant and equipment		1,251
Accounts payable		-18
Other current liabilities		-17
Deferred credits and other liabilities		-259
Long-term debt, including current portion		-260
Total assets acquired/liabilities assumed		798
Goodwill		$523

Business_Segments_Additional_I

Business Segments - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014
	reportable_segments
DCP Midstream, LLC | DCP Midstream Partners, LP
Segment Reporting Information [Line Items]
Percentage of ownership interests	22.00%
Total Reportable Segments
Segment Reporting Information [Line Items]
Number of reportable segments	4
Spectra Energy Corp | DCP Midstream, LLC
Segment Reporting Information [Line Items]
Percentage of ownership interests	50.00%
Phillips 66 | DCP Midstream, LLC
Segment Reporting Information [Line Items]
Percentage of ownership interests	50.00%

Business_Segment_Data_Detail

Business Segment Data (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$1,600	$1,207	$1,253	$1,843	$1,565	$1,144	$1,220	$1,589	$5,903	[1]	$5,518	[1]	$5,075	[1]
Depreciation and Amortization									796	[1]	772	[1]	746	[1]
Capital and Investment Expenditures									2,287	[2],[3]	2,259	[2],[3]	2,545	[2],[3]
Assets	34,040				33,533				34,040		33,533		30,587
Interest expense									679		657		625
Earnings From Continuing Operations Before Income Taxes									1,665	[1]	1,578	[1]	1,415	[1]
Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									5,903		5,518		5,075
Intersegment Revenues
Segment Reporting Information [Line Items]
Operating revenues									0		0		0
Operating Segments
Segment Reporting Information [Line Items]
Depreciation and Amortization									796	[1]	772	[1]	746	[1]
Interest expense									679	[1]	657	[1]	625	[1]
Interest income and other									6	[1]	7	[1]	3	[1]
Eliminations
Segment Reporting Information [Line Items]
Operating revenues									-183	[1]	-134	[1]	-113	[1]
Assets	-58				-499				-58		-499		-539
Spectra Energy Partners | Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									2,269		1,964		1,754
Spectra Energy Partners | Intersegment Revenues
Segment Reporting Information [Line Items]
Operating revenues									0		1		0
Spectra Energy Partners | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues									2,269	[1]	1,965	[1]	1,754	[1]
Earnings Before Interest Taxes Depreciation And Amortization									1,669	[1]	1,433	[1]	1,259	[1]
Depreciation and Amortization									290	[1]	263	[1]	232	[1]
Capital and Investment Expenditures									1,241	[2],[3]	1,299	[2],[3]	1,443	[2],[3]
Assets	17,865				16,800				17,865		16,800		13,856
Distribution | Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									1,843		1,848		1,666
Distribution | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues									1,843	[1]	1,848	[1]	1,666	[1]
Earnings Before Interest Taxes Depreciation And Amortization									552	[1]	574	[1]	587	[1]
Depreciation and Amortization									192	[1]	199	[1]	213	[1]
Capital and Investment Expenditures									427	[2],[3]	357	[2],[3]	276	[2],[3]
Assets	6,064				6,009				6,064		6,009		5,842
Western Canada Transmission & Processing | Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									1,781		1,694		1,645
Western Canada Transmission & Processing | Intersegment Revenues
Segment Reporting Information [Line Items]
Operating revenues									121		73		34
Western Canada Transmission & Processing | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues									1,902	[1]	1,767	[1]	1,679	[1]
Earnings Before Interest Taxes Depreciation And Amortization									754	[1]	736	[1]	694	[1]
Depreciation and Amortization									271	[1]	272	[1]	245	[1]
Capital and Investment Expenditures									473	[2],[3]	561	[2],[3]	760	[2],[3]
Assets	6,916				7,160				6,916		7,160		7,226
Field Services | Operating Segments
Segment Reporting Information [Line Items]
Earnings Before Interest Taxes Depreciation And Amortization									217	[1]	343	[1]	279	[1]
Assets	1,345				1,365				1,345		1,365		1,235
Total Reportable Segments | Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									5,893		5,506		5,065
Total Reportable Segments | Intersegment Revenues
Segment Reporting Information [Line Items]
Operating revenues									121		74		34
Total Reportable Segments | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues									6,014	[1]	5,580	[1]	5,099	[1]
Earnings Before Interest Taxes Depreciation And Amortization									3,192	[1]	3,086	[1]	2,819	[1]
Depreciation and Amortization									753	[1]	734	[1]	690	[1]
Capital and Investment Expenditures									2,141	[2],[3]	2,217	[2],[3]	2,479	[2],[3]
Assets	32,190				31,334				32,190		31,334		28,159
Other | Unaffiliated Revenues
Segment Reporting Information [Line Items]
Operating revenues									10		12		10
Other | Intersegment Revenues
Segment Reporting Information [Line Items]
Operating revenues									62		60		79
Other | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues									72	[1]	72	[1]	89	[1]
Earnings Before Interest Taxes Depreciation And Amortization									-58	[1]	-86	[1]	-36	[1]
Depreciation and Amortization									43	[1]	38	[1]	56	[1]
Capital and Investment Expenditures									146	[2],[3]	42	[2],[3]	66	[2],[3]
Assets	$1,908				$2,698				$1,908		$2,698		$2,967
[1]	Excludes amounts associated with entities included in discontinued operations.
[2]	Excludes a $71 million loan to an unconsolidated affiliate in 2013 at Spectra Energy Partners.
[3]	Excludes the $1,254 million cash outlay for the acquisition of Express-Platte in March 2013 and $30 million paid in 2012 for amounts previously withheld from the purchase price consideration of the acquisition of Bobcat in 2010, all part of Spectra Energy Partners.

Business_Segment_Data_Notes_De

Business Segment Data (Notes) (Detail) (USD $)	12 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2013
Segment Reporting Information [Line Items]
Purchase price	$0	$1,254	$30
Unconsolidated affiliates | Spectra Energy Partners, LP
Segment Reporting Information [Line Items]
Loan receivable including accrued interest		71
Spectra Energy Partners | Express-Platte
Segment Reporting Information [Line Items]
Purchase price				1,254
Spectra Energy Partners | Bobcat
Segment Reporting Information [Line Items]
Purchase price			$30

Business_Segments_Geographic_D

Business Segments - Geographic Data (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Consolidated revenues	$1,600	$1,207	$1,253	$1,843	$1,565	$1,144	$1,220	$1,589	$5,903	[1]	$5,518	[1]	$5,075	[1]
Consolidated long-lived assets	28,591				28,257				28,591		28,257		25,827
United States
Segment Reporting Information [Line Items]
Consolidated revenues									2,212		1,926		1,762	[2]
Consolidated long-lived assets	15,859				14,993				15,859		14,993		10,952
Canada
Segment Reporting Information [Line Items]
Consolidated revenues									3,691		3,592		3,313	[2]
Consolidated long-lived assets	$12,732				$13,264				$12,732		$13,264		$14,875
[1]	Excludes amounts associated with entities included in discontinued operations.
[2]	Excludes revenues associated with businesses included in discontinued operations.

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$1,494	[1],[2]	$1,376	[1],[2]
Regulatory Liabilities	430	[2]	510	[2]
Removal Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	326	[2],[3],[4],[5]	359	[2],[3],[4],[5]
FT-RAM optimization
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	0	[2],[6]	31	[2],[6]
Regulatory Liability Recovery/Refund Period Ends	2014
Gas Purchase Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	0	[2],[6],[7]	7	[2],[6],[7]
Regulatory Liability Recovery/Refund Period Ends	2014
Pipeline Rate Credit
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	25	[2],[4],[8]	27	[2],[4],[8]
Over-recovery of Fuel Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	0	[2],[6],[7]	35	[2],[6],[7]
Regulatory Liability Recovery/Refund Period Ends	2014
Other
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liabilities	79	[2],[3],[9]	51	[2],[3],[9]
Net Regulatory Asset Related to Income Taxes
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	1,271	[1],[10],[2],[3],[8]	1,224	[1],[10],[2],[3],[8]
Project Development Costs
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	10	[1],[2]	14	[1],[2]
Regulatory Asset Recovery/Refund Period Ends	2036
Vacation Accrual
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	22	[1],[11],[2]	21	[1],[11],[2]
Deferred Debt Expense/Premium
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	31	[1],[2],[3],[8]	32	[1],[2],[3],[8]
Under-recovery of Fuel Costs (Included in Other Current Assets)
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	44	[1],[12],[13],[2]	28	[1],[12],[13],[2]
Regulatory Asset Recovery/Refund Period Ends	2015
Gas Purchase Costs Asset [Domain]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	57	[1],[12],[2],[7]
Regulatory Asset Recovery/Refund Period Ends	2015
Other Assets
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets	$59	[1],[2],[9]	$57	[1],[2],[9]
[1]	Included in Regulatory Assets and Deferred Debits unless otherwise noted.
[2]	All regulatory assets and liabilities are excluded from rate base unless otherwise noted.
[3]	All or a portion of the balance is included in rate base.
[4]	Included in Deferred Credits and Other Liabilities — Regulatory and Other.
[5]	Liability is extinguished as the associated assets are retired.
[6]	Included in Other Current Liabilities.
[7]	Includes certain costs which are settled in cash annually through transportation rates in accordance with FERC and/or OEB gas tariffs.
[8]	Recovery/refund is over the life of the associated asset or liability.
[9]	The majority of this balance has a recovery period of less than one year. The recovery/refund period for the remainder is currently unknown.
[10]	All amounts are expected to be included in future rate filings.
[11]	Recoverable in future periods.
[12]	Included in Other Current Assets.
[13]	Amounts settled in cash annually through transportation rates in accordance with FERC gas tariffs.

Regulatory_Matters_Additional_

Regulatory Matters - Additional Information (Detail) (USD $)	12 Months Ended						3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Mar. 31, 2014	Jun. 30, 2014
Regulatory Matters [Line Items]
Regulatory assets	$1,494	[1],[2]	$1,376	[1],[2]
Regulatory liabilities	430	[2]	510	[2]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	1,665	[3]	1,578	[3]	1,415	[3]
Transportation, storage and processing of natural gas	3,291		3,128		3,149
Sales of natural gas liquids	497		440		401
Other Revenue, Net	230		149		159
Union Gas Limited | Deferred Income Tax Assets/Liabilities
Regulatory Matters [Line Items]
Regulatory assets	303		308
Union Gas Limited | Customer Receipts
Regulatory Matters [Line Items]
Regulatory assets	57
BC Pipeline and BC Field Services | Deferred Income Tax Assets/Liabilities
Regulatory Matters [Line Items]
Regulatory assets	795		774
Regulatory asset recovery period, minimum	20 years
Regulatory assets recovery period, maximum	30 years
Removal Costs
Regulatory Matters [Line Items]
Regulatory liabilities	326	[2],[4],[5],[6]	359	[2],[4],[5],[6]
Removal Costs | Union Gas Limited
Regulatory Matters [Line Items]
Regulatory liabilities	322		354
Customer Receipts | Union Gas Limited
Regulatory Matters [Line Items]
Regulatory liabilities	7
Accounts payable | Union Gas Limited
Regulatory Matters [Line Items]
Public Utilities, Description of Specific Regulatory Liabilities	19
Accounts Receivable [Member] | Union Gas Limited
Regulatory Matters [Line Items]
Public Utilities, Description of Specific Regulatory Liabilities	9
Unfavorable Regulatory Action [Member] | Union Gas Limited
Regulatory Matters [Line Items]
Sales of natural gas liquids							15
Other Revenue, Net							7
Favorable Regulatory Action [Member] | Union Gas Limited
Regulatory Matters [Line Items]
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest							10	7
Transportation, storage and processing of natural gas							$32
[1]	Included in Regulatory Assets and Deferred Debits unless otherwise noted.
[2]	All regulatory assets and liabilities are excluded from rate base unless otherwise noted.
[3]	Excludes amounts associated with entities included in discontinued operations.
[4]	Liability is extinguished as the associated assets are retired.
[5]	Included in Deferred Credits and Other Liabilities — Regulatory and Other.
[6]	All or a portion of the balance is included in rate base.

Income_Taxes_Income_Tax_Expens

Income Taxes - Income Tax Expense Components (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current income taxes
Federal	$1	($32)	$102
State	3	4	5
Foreign	-10	26	52
Total current income taxes	-6	-2	159
Deferred income taxes
Federal	335	353	174
State	-17	69	33
Foreign	70	-1	4
Total deferred income taxes	388	421	211
Income tax expense from continuing operations	382	419	370
Income tax expense from discontinued operations	0	0	2
Total income tax expense	$382	$419	$372

Income_Taxes_Earnings_from_Con

Income Taxes - Earnings from Continuing Operations before Income Taxes (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Income Tax Disclosure [Abstract]
Domestic	$1,108		$1,059		$912
Foreign	557		519		503
Earnings From Continuing Operations Before Income Taxes	$1,665	[1]	$1,578	[1]	$1,415	[1]
[1]	Excludes amounts associated with entities included in discontinued operations.

Income_Taxes_Reconciliation_of

Income Taxes - Reconciliation of Income Tax Expense at U.S. Federal Statutory Tax Rate to Actual Income Tax Expense from Continuing Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Income tax expense, computed at the statutory rate of 35%	$583	$552	$495
State income tax, net of federal income tax effect	25	20	19
Tax differential on foreign earnings	-125	-147	-110
Noncontrolling interests	-70	-42	-37
Valuation allowance	2	-3	1
Revaluation of accumulated deferred state income taxes	-25	31	0
Other items, net	-8	8	2
Income tax expense from continuing operations	$382	$419	$370
Effective tax rate	22.90%	26.60%	26.10%

Income_Taxes_Reconciliation_of1

Income Taxes - Reconciliation of Income Tax Expense at U.S. Federal Statutory Tax Rate to Actual Income Tax Expense from Continuing Operations (notes) (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Income tax expense, statutory rate	35.00%	35.00%	35.00%

Income_Taxes_Net_Deferred_Inco

Income Taxes - Net Deferred Income Tax Liability Components (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Income Tax Disclosure [Abstract]
Deferred credits and other liabilities	$225	$242
Other	211	291
Total deferred income tax assets	436	533
Valuation allowance	-29	-29
Net deferred income tax assets	407	504
Investments and other assets	-1,531	-1,004
Accelerated depreciation rates	-3,875	-4,092
Regulatory assets and deferred debits	-426	-383
Total deferred income tax liabilities	-5,832	-5,479
Total net deferred income tax liabilities	($5,425)	($4,975)

Income_Taxes_Deferred_Tax_Amou

Income Taxes - Deferred Tax Amounts Classified in Consolidated Balance Sheets (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Income Tax Disclosure [Abstract]
Other current assets	$0	$9
Other current liabilities	-20	-16
Deferred credits and other liabilities	-5,405	-4,968
Total net deferred income tax liabilities	($5,425)	($4,975)

Income_Taxes_Reconciliation_of2

Income Taxes - Reconciliation of Gross Unrecognized Income Tax Benefits (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$76	$80	$76
Increases related to prior year tax positions	10	7	5
Decreases related to prior year tax positions	-6	-17	0
Increases related to current year tax positions	1	2	2
Settlements	0	-3	-2
Lapse of statute of limitations	-30	9	-2
Foreign currency translation	-1	-2	1
Balance at end of period	$50	$76	$80

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Contingency [Line Items]
Unrecognized tax benefits	$50,000,000	$76,000,000	$80,000,000	$76,000,000
Unrecognized tax benefits that would reduce the annual effective tax rate if recognized in next fiscal year	33,000,000
Net decrease in gross uncertain tax benefits	26,000,000
Uncertain tax benefits, deferred tax liabilities and foreign currency exchange rate fluctuations	27,000,000
Uncertain tax benefits, increase in income tax expense	1,000,000
Interest income related to unrecognized tax benefits	2,000,000	4,000,000
Accrued interest and penalties	19,000,000	21,000,000
Significant (Increase) Decrease in Unrecognized Tax Benefits is Reasonably Possible, Estimated Range of Change, Lower Bound	15,000,000
Significant (Increase) Decrease in Unrecognized Tax Benefits is Reasonably Possible, Estimated Range of Change, Upper Bound	20,000,000
Undistributed earnings of foreign subsidiaries	1,800,000,000
United States
Income Tax Contingency [Line Items]
Net operating loss carryforward	379,000,000
Deferred tax asset attributable to state net operating loss and credit carryovers	133,000,000
Valuation allowance against deferred tax asset attributable to state net operating loss and credit carryovers	9,000,000
United States | Minimum
Income Tax Contingency [Line Items]
Subject to examination income tax return fillings, date	2007
United States | Maximum
Income Tax Contingency [Line Items]
Subject to examination income tax return fillings, date	2013
Federal | Minimum
Income Tax Contingency [Line Items]
Net operating loss carryforwards, expiration date	2021
State
Income Tax Contingency [Line Items]
Net operating loss carryforward	299,000,000
Deferred tax asset attributable to state net operating loss and credit carryovers	15,000,000
Valuation allowance against deferred tax asset attributable to state net operating loss and credit carryovers		7,000,000
Foreign Country
Income Tax Contingency [Line Items]
Net operating loss carryforward	40,000,000
Deferred tax asset attributable to state net operating loss and credit carryovers	10,000,000
Capital loss carryforward	151,000,000
Capital loss carryforward, expiration date	indefinite
Deferred tax asset attributable to foreign capital loss carryforward	20,000,000
Valuation allowance against deferred tax asset related to foreign capital loss carryforward	$20,000,000	$22,000,000
Foreign Country | Minimum
Income Tax Contingency [Line Items]
Net operating loss carryforwards, expiration date	2015
Canada | Minimum
Income Tax Contingency [Line Items]
Subject to examination income tax return fillings, date	2009
Canada | Maximum
Income Tax Contingency [Line Items]
Subject to examination income tax return fillings, date	2013

Discontinued_Operations_Result

Discontinued Operations - Results Classified as Income from Discontinued Operations, Net of Tax in Consolidated Statements of Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discontinued Operations and Disposal Groups [Abstract]
Operating revenues			$99
Pre-tax earnings			4
Income tax expense	0	0	2
Income from discontinued operations, net of tax	$0	$0	$2

Earnings_Per_Common_Share_Addi

Earnings Per Common Share - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Number of options and stock awards not included in the calculation of diluted EPS (in shares)	0	0	1,000,000

Earnings_per_Common_Share_Basi

Earnings per Common Share - Basic and Diluted Eps Calculations (Detail) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Basic (in usd per share)	$0.47	[1]	$0.30	[1]	$0.22	[1]	$0.63	[1]	$0.35	[1]	$0.39	[1]	$0.30	[1]	$0.51	[1]	$1.61	[1]	$1.55	[1]	$1.44
Diluted (in usd per share)	$0.47	[1]	$0.30	[1]	$0.22	[1]	$0.62	[1]	$0.35	[1]	$0.39	[1]	$0.30	[1]	$0.51	[1]	$1.61	[1]	$1.55	[1]	$1.43
Income from continuing operations, net of tax - controlling interests																	$1,082		$1,038		$938
Income from discontinued operations, net of tax - controlling interests																	0		0		2
Net Income — Controlling Interests	$316		$201		$146		$419		$236		$263		$199		$340		$1,082		$1,038		$940
Weighted average common shares, outstanding
Basic (in shares)																	671		669		653
Diluted (in shares)																	672		671		656
[1]	Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to rounding.

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance at beginning of period	$1,241	$1,509
Reclassified to net income	5	7
Other AOCI activity	-584	-275
Balance at end of period	662	1,241
Foreign Currency Translation Adjustments
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance at beginning of period	1,557	2,044
Reclassified to net income	0	0
Other AOCI activity	-541	-487
Balance at end of period	1,016	1,557
Pension and Post-retirement Benefit Plan Obligations
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance at beginning of period	-304	-507
Reclassified to net income	0	0
Other AOCI activity	-47	203
Balance at end of period	-351	-304
Gas Purchase Contract Hedges
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance at beginning of period	-11	-23
Reclassified to net income	4	6
Other AOCI activity	4	6
Balance at end of period	-3	-11
Other
Increase (Decrease) in Accumulated Other Comprehensive Income [Roll Forward]
Balance at beginning of period	-1	-5
Reclassified to net income	1	1
Other AOCI activity	0	3
Balance at end of period	$0	($1)

Inventory_Components_of_Invent

Inventory - Components of Inventory (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Inventory Disclosure [Abstract]
Natural gas	$211	$155
NGLs	28	30
Materials and supplies	74	78
Total inventory	$313	$263

Inventory_Additional_Informati

Inventory - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Inventories [Line Items]
Natural gas and petroleum products purchased	$1,219	$1,139	$1,037
Western Canada Transmission & Processing | Empress Operations
Inventories [Line Items]
Natural gas and petroleum products purchased	19
Natural gas and petroleum products purchased, net of tax	$14

Investments_in_and_Loans_to_Un2

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions - Additional Information (Detail) (USD $)	0 Months Ended	12 Months Ended					1 Months Ended
In Millions, unless otherwise specified	Nov. 01, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012		Nov. 30, 2012
Schedule of Equity Method Investments [Line Items]
Distributions from equity investments		$646	$411		$324
Cumulative undistributed earnings of unconsolidated affiliates		482	507
Equity in earnings of unconsolidated affiliates		361	445		382
Revenues associated with a propane sales agreement with an affiliate of DCP Midstream					99
Transportation, storage and processing of natural gas		3,291	3,128		3,149
Sales of natural gas liquids		497	440		401
Distributions received from unconsolidated affiliates		380	324		307
Cash purchase price	2,300
Recoveries of costs from affiliates		38	68		70
Outstanding receivables from affiliates		1	23
Spectra Energy Capital, LLC
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates		0	0	[1]	0	[2]
Distributions received from unconsolidated affiliates		0	0	[1]	0	[2]
Sand Hills and Southern Hills
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		33.33%
Cash purchase price			459				459
Steckman Ridge LP
Schedule of Equity Method Investments [Line Items]
Interest income on loan		1	1		1
Steckman Ridge LP | Maximum
Schedule of Equity Method Investments [Line Items]
Loan receivable due date		1-Oct-23
Steckman Ridge LP | Spectra Energy Partners, LP
Schedule of Equity Method Investments [Line Items]
Loan receivable including accrued interest		71
Steckman Ridge LP | Spectra Energy Capital, LLC
Schedule of Equity Method Investments [Line Items]
Loan receivable including accrued interest			71
DCP Midstream, LLC
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		50.00%
Equity in earnings of unconsolidated affiliates		73	98		36
Other operating revenue		79	48		53
Revenues associated with a propane sales agreement with an affiliate of DCP Midstream					99
Transportation, storage and processing of natural gas		9	9		12
Sales of natural gas liquids		7	8		14
Accounts receivable from DCP Midstream and its affiliates		1	1
Distributions received from unconsolidated affiliates		237	215		203
Spectra Energy Partners
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates		133	90		89
Spectra Energy Partners | Gulfstream
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		41.00%
Spectra Energy Partners | Southeast Supply Header
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		41.00%
Spectra Energy Partners | Steckman Ridge LP
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		41.00%
Other Segment | Southeast Supply Header
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		0.10%
Field Services
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates		$217	$343		$279
Field Services | Sand Hills and Southern Hills
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		4.00%
Field Services | Spectra Energy Partners
Schedule of Equity Method Investments [Line Items]
Percentage of ownership		27.00%
[1]	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
[2]	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Investments_in_and_Loans_to_Un3

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions - Investments in and Loans to Unconsolidated Affiliates (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	$2,966	$3,043
Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	2,934	2,961
International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	32	82
Spectra Energy Partners
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1,588	1,396
Spectra Energy Partners | Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1,588	1,396
Spectra Energy Partners | International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	0	0
Distribution
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	14	16
Distribution | Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	0	0
Distribution | International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	14	16
Western Canada Transmission & Processing
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	18	66
Western Canada Transmission & Processing | Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	0	0
Western Canada Transmission & Processing | International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	18	66
Field Services
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1,345	1,365
Field Services | Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1,345	1,365
Field Services | International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	0	0
Other
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1	200
Other | Domestic
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	1	200
Other | International
Investments in and Advances to Affiliates [Line Items]
Investments in and loans to unconsolidated affiliates	$0	$0

Investments_in_and_Loans_to_Un4

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions - Equity in Earnings of Unconsolidated Affiliates (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	$361	$445	$382
Spectra Energy Partners
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	133	90	89
Distribution
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	1	1	0
Western Canada Transmission & Processing
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	1	-1	1
Field Services
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	217	343	279
Other
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	9	12	13
Domestic
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	359	445	381
Domestic | Spectra Energy Partners
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	133	90	89
Domestic | Distribution
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	0	0	0
Domestic | Western Canada Transmission & Processing
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	0	0	0
Domestic | Field Services
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	217	343	279
Domestic | Other
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	9	12	13
International
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	2	0	1
International | Spectra Energy Partners
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	0	0	0
International | Distribution
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	1	1	0
International | Western Canada Transmission & Processing
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	1	-1	1
International | Field Services
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	0	0	0
International | Other
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	$0	$0	$0

Investments_in_and_Loans_to_Un5

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions - Summarized Statements of Operations of Unconsolidated Affiliates Presented at 100 Percent (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Related Party Transaction [Line Items]
Operating revenues	$1,600	$1,207	$1,253	$1,843	$1,565	$1,144	$1,220	$1,589	$5,903	[1]	$5,518	[1]	$5,075	[1]
Operating expenses									3,979		3,852		3,500
Operating Income	565	382	338	639	473	333	354	506	1,924		1,666		1,575
Net income	374	254	188	467	271	292	226	370	1,283		1,159		1,047
Net income attributable to members' interests	316	201	146	419	236	263	199	340	1,082		1,038		940
Unconsolidated affiliates
Related Party Transaction [Line Items]
Operating revenues									14,757		12,596		10,682
Operating expenses									13,581		11,491		9,644
Operating Income									1,176		1,105		1,038
Net income									868		790		786
Net income attributable to members' interests									620		697		689
Unconsolidated affiliates | DCP Midstream, LLC
Related Party Transaction [Line Items]
Operating revenues									14,013		12,038		10,171
Operating expenses									13,262		11,230		9,427
Operating Income									751		808		744
Net income									536		584		583
Net income attributable to members' interests									288		491		486
Unconsolidated affiliates | Other
Related Party Transaction [Line Items]
Operating revenues									744		558		511
Operating expenses									319		261		217
Operating Income									425		297		294
Net income									332		206		203
Net income attributable to members' interests									$332		$206		$203
[1]	Excludes amounts associated with entities included in discontinued operations.

Investments_in_and_Loans_to_Un6

Investments in and Loans to Unconsolidated Affiliates and Related Party Transactions - Summarized Balance Sheets of Unconsolidated Affiliates Presented at 100 Percent (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Related Party Transaction [Line Items]
Current assets	$2,332	$2,081
Current liabilities	-3,809	-4,039
Total equity	10,398	10,323	9,843	8,896
Equity - noncontrolling interests	-2,238	-1,829
Equity — controlling interests	8,160	8,494
Unconsolidated affiliates
Related Party Transaction [Line Items]
Current assets	1,621	1,911
Non-current assets	17,657	16,506
Current liabilities	-3,570	-3,257
Non-current liabilities	-6,735	-6,888
Total equity	8,973	8,272
Equity - noncontrolling interests	-2,578	-1,725
Equity — controlling interests	6,395	6,547
Unconsolidated affiliates | DCP Midstream, LLC
Related Party Transaction [Line Items]
Current assets	1,380	1,663
Non-current assets	12,299	11,058
Current liabilities	-2,938	-3,114
Non-current liabilities	-5,538	-5,218
Total equity	5,203	4,389
Equity - noncontrolling interests	-2,578	-1,725
Equity — controlling interests	2,625	2,664
Unconsolidated affiliates | Other
Related Party Transaction [Line Items]
Current assets	241	248
Non-current assets	5,358	5,448
Current liabilities	-632	-143
Non-current liabilities	-1,197	-1,670
Total equity	3,770	3,883
Equity - noncontrolling interests	0	0
Equity — controlling interests	$3,770	$3,883

Goodwill_Components_and_Activi

Goodwill - Components and Activity within Goodwill (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Mar. 14, 2013
Goodwill [Roll Forward]
Beginning balance	$4,810	$4,513
Acquisition of Express-Platte	37	486
Foreign currency translation	-133	-189
Ending balance	4,714	4,810
Spectra Energy Partners
Goodwill [Roll Forward]
Beginning balance	3,215	2,814
Foreign currency translation	-8	-85
Ending balance	3,244	3,215
Distribution
Goodwill [Roll Forward]
Beginning balance	824	878
Foreign currency translation	-65	-54
Ending balance	759	824
Western Canada Transmission & Processing
Goodwill [Roll Forward]
Beginning balance	771	821
Foreign currency translation	-60	-50
Ending balance	711	771
Express Platte
Goodwill [Roll Forward]
Beginning balance			523
Ending balance			523
Express Platte | Spectra Energy Partners
Goodwill [Roll Forward]
Acquisition of Express-Platte	37	486
Express Platte | Distribution
Goodwill [Roll Forward]
Acquisition of Express-Platte	0	0
Express Platte | Western Canada Transmission & Processing
Goodwill [Roll Forward]
Acquisition of Express-Platte	$0	$0

Goodwill_Amounts_Originating_f

Goodwill - Amounts Originating from Acquisition of Westcoast Energy Inc. (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Goodwill [Line Items]
Goodwill	$4,714	$4,810	$4,513
Distribution
Goodwill [Line Items]
Goodwill	759	824	878
Western Canada Transmission & Processing
Goodwill [Line Items]
Goodwill	711	771	821
Westcoast Energy Inc. | Distribution
Goodwill [Line Items]
Goodwill	757	821
Westcoast Energy Inc. | Western Canada Transmission & Processing
Goodwill [Line Items]
Goodwill	$677	$736

Marketable_Securities_and_Rest2

Marketable Securities and Restricted Funds - Estimated Fair Values of Available for Sale Securities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule of Available-for-sale Securities [Line Items]
Total available-for-sale securities	$24	$19
Corporate Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Total available-for-sale securities	23	18
Money Market Funds
Schedule of Available-for-sale Securities [Line Items]
Total available-for-sale securities	$1	$1

Marketable_Securities_and_Rest3

Marketable Securities and Restricted Funds - Restricted and Nonrestricted AFS Securities by Balance Sheet Classification Table Text (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule of Available-for-sale Securities [Line Items]
Total available-for-sale securities	$24	$19
Investments and Other Assets - Other
Schedule of Available-for-sale Securities [Line Items]
Investments and other assets—other	1	1
Investments and other assets—other	20	11
Current Assets - Other
Schedule of Available-for-sale Securities [Line Items]
Current assets—other	$3	$7

Estimated_Fair_Values_of_Held_

- Estimated Fair Values of Held to Maturity Securities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	$172	$213
Current Assets - Other | Bankers Acceptance
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	38	35
Current Assets - Other | Canadian Government Securities
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	30	34
Current Assets - Other | Money Market Funds
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	3	3
Investments and Other Assets - Other | Bankers Acceptance
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	0	10
Investments and Other Assets - Other | Canadian Government Securities
Schedule of Held-to-maturity Securities [Line Items]
Total held-to-maturity securities	$101	$131

Marketable_Securities_and_Rest4

Marketable Securities and Restricted Funds - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Gain (Loss) on Investments [Line Items]
Proceeds from the issuance of long-term debt	$1,028	$4,372	$1,301
Spectra Energy Partners, LP
Gain (Loss) on Investments [Line Items]
Proceeds from the issuance of long-term debt		1,900
M&N Canada 6.90% senior secured notes due 2014 to 2019 | Maritimes & Northeast Pipeline Limited Partnership
Gain (Loss) on Investments [Line Items]
Debt instrument, interest rate, stated percentage	6.90%
Current Assets - Other
Gain (Loss) on Investments [Line Items]
Restricted funds	13	19
Investments and Other Assets - Other
Gain (Loss) on Investments [Line Items]
Restricted funds	6
Other Income
Gain (Loss) on Investments [Line Items]
Interest income	$4	$6	$6
Maximum | Available-for-sale Securities
Gain (Loss) on Investments [Line Items]
Other restricted available for sale securities, current	2 years
Maximum | Held-to-maturity Securities
Gain (Loss) on Investments [Line Items]
Other restricted available for sale securities, current	1 year

Property_Plant_and_Equipment_D

Property Plant and Equipment (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	29,211	$28,456
Total accumulated depreciation	-6,543	-6,258
Total accumulated amortization	-361	-369
Net property, plant and equipment	22,307	21,829
Plant | Natural Gas Transmission
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	15,001	14,491
Plant | Natural Gas Transmission | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	15 years
Plant | Natural Gas Transmission | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	100 years
Plant | Natural Gas Distribution
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	2,971	3,076
Plant | Natural Gas Distribution | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	25 years
Plant | Natural Gas Distribution | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	60 years
Plant | Gathering and Processing Facilities
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	4,765	4,848
Plant | Gathering and Processing Facilities | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	25 years
Plant | Gathering and Processing Facilities | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	40 years
Plant | Natural Gas Storage
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	2,162	2,113
Plant | Natural Gas Storage | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	10 years
Plant | Natural Gas Storage | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	122 years
Plant | Crude Oil Transportation and Storage
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	1,169	1,243
Plant | Crude Oil Transportation and Storage | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	30 years
Plant | Crude Oil Transportation and Storage | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	75 years
Plant | Land Rights and Rights of Way
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	568	562
Plant | Land Rights and Rights of Way | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	21 years
Plant | Land Rights and Rights of Way | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	122 years
Plant | Other Buildings and Improvements
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	132	134
Plant | Other Buildings and Improvements | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	10 years
Plant | Other Buildings and Improvements | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	50 years
Equipment
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	343	341
Equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	3 years
Equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	40 years
Vehicles
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	114	115
Vehicles | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	5 years
Vehicles | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	20 years
Land
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	150	128
Construction in Process
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	1,113	630
Software
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	387	438
Software | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	4 years
Software | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	10 years
Other
Property, Plant and Equipment [Line Items]
Total property, plant and equipment	336	$337
Other | Minimum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	5 years
Other | Maximum
Property, Plant and Equipment [Line Items]
Estimated Useful Life	82 years

Property_Plant_and_Equipment_E

Property, Plant and Equipment - Estimated Amortization Expense for Next Five Years (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Estimated Amortization Expense
2015	$80
2016	68
2017	57
2018	44
2019	$34

Property_Plant_And_Equipment_A

Property, Plant And Equipment - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Abstract]
Percentage of public utilities property plant and equipment regulated with estimated useful lives based on rates approved by regulatory authorities	85.00%
Composite weighted-average depreciation rates	2.82%	2.96%	3.14%
Amortization expense of intangible assets	$74	$65	$81

Reconciliation_of_Changes_in_A

Reconciliation of Changes in Asset Retirement Obligation Liabilities (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of year	$350	[1]	$188
Accretion expense	16		9
Revisions in estimated cash flows	72	[2]	172	[2]
Foreign currency exchange impact	-28		-12
Liabilities settled	-10		-7
Balance at end of year	$400	[1]	$350	[1]
[1]	Amounts included in Deferred Credits and Other Liabilities in the Consolidated Balance Sheets.
[2]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlZDAxNDIxYzllMzRkYThhMjhkNDRlNWRhYTk4Y2Q4fFRleHRTZWxlY3Rpb246NkJBNkRGOEY5NTYxMjEyREY4NjQyQjVERUIxRDUyODYM}

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Reconciliation Of Changes In Asset Retirement Obligations [Line Items]
Asset retirement obligation, revision of estimate	$72	[1]	$172	[1]
Western Canada Transmission & Processing
Reconciliation Of Changes In Asset Retirement Obligations [Line Items]
Asset retirement obligation, revision of estimate	$44	[1]
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlZDAxNDIxYzllMzRkYThhMjhkNDRlNWRhYTk4Y2Q4fFRleHRTZWxlY3Rpb246NkJBNkRGOEY5NTYxMjEyREY4NjQyQjVERUIxRDUyODYM}

Debt_and_Credit_Facilities_Sum

Debt and Credit Facilities - Summary of Debt and Related Terms (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]
Long-term debt principal (including current maturities)	$13,060		$13,668
Change in fair value of debt hedged	17		17
Unamortized debt discount, net	-12		-12
Other unamortized items	7		12
Total other non-principal amounts	12		17
Commercial paper	1,583	[1],[2]	1,032	[1],[2]
Capital Leases	24		0
Total debt (including capital lease obligations)	14,679	[3]	14,717	[3]
Current maturities of long-term debt	-327		-1,197
Total long-term debt (including capital lease obligations)	12,769		12,488
Secured debt	379
Spectra Energy Capital, LLC
Debt Instrument [Line Items]
Long-term debt principal (including current maturities)	2,890		3,147
Commercial paper	398		344
Spectra Energy Capital, LLC | 5.50% senior unsecured notes due March 2014
Debt Instrument [Line Items]
Unsecured debt	0		149
Spectra Energy Capital, LLC | 5.67% senior unsecured notes due August 2014
Debt Instrument [Line Items]
Unsecured debt	0		408
Spectra Energy Capital, LLC | 6.20% senior unsecured notes due April 2018
Debt Instrument [Line Items]
Unsecured debt	500		500
Spectra Energy Capital, LLC | 6.75% senior unsecured notes due July 2018
Debt Instrument [Line Items]
Unsecured debt	150		150
Spectra Energy Capital, LLC | Variable-rate senior unsecured term loan due November 2018
Debt Instrument [Line Items]
Unsecured debt	300		0
Spectra Energy Capital, LLC | 8.00% senior unsecured notes due October 2019
Debt Instrument [Line Items]
Unsecured debt	500		500
Spectra Energy Capital, LLC | 5.65% senior unsecured notes due March 2020
Debt Instrument [Line Items]
Unsecured debt	300		300
Spectra Energy Capital, LLC | 3.30% senior unsecured notes due March 2023
Debt Instrument [Line Items]
Unsecured debt	650		650
Spectra Energy Capital, LLC | 6.75% senior unsecured notes due February 2032
Debt Instrument [Line Items]
Unsecured debt	240		240
Spectra Energy Capital, LLC | 7.50% senior unsecured notes due September 2038
Debt Instrument [Line Items]
Unsecured debt	250		250
SEP
Debt Instrument [Line Items]
Long-term debt principal (including current maturities)	5,184		5,625
SEP | SEP 2.95% senior unsecured notes due June 2016
Debt Instrument [Line Items]
Unsecured debt	250		250
SEP | SEP 2.95% senior unsecured notes due September 2018
Debt Instrument [Line Items]
Unsecured debt	500		500
SEP | SEP Variable-rate senior unsecured term loan due November 2018
Debt Instrument [Line Items]
Unsecured debt	400		400
SEP | SEP 4.60% senior unsecured notes due June 2021
Debt Instrument [Line Items]
Unsecured debt	250		250
SEP | SEP 4.75% senior unsecured notes due March 2024
Debt Instrument [Line Items]
Unsecured debt	1,000		1,000
SEP | SEP 5.95% senior unsecured notes due September 2043
Debt Instrument [Line Items]
Unsecured debt	400		400
Texas Eastern | Texas Eastern 6.00% senior unsecured notes due September 2017
Debt Instrument [Line Items]
Unsecured debt	400		400
Texas Eastern | Texas Eastern 4.13% senior unsecured notes due December 2020
Debt Instrument [Line Items]
Unsecured debt	300		300
Texas Eastern | Texas Eastern 2.80% senior unsecured notes due October 2022
Debt Instrument [Line Items]
Unsecured debt	500		500
Texas Eastern | Texas Eastern 7.00% senior unsecured notes due July 2032
Debt Instrument [Line Items]
Unsecured debt	450		450
Algonquin | Algonquin 3.51% senior notes due July 2024
Debt Instrument [Line Items]
Unsecured debt	350		350
East Tennessee Natural Gas, LLC | East Tennessee Natural Gas, LLC 3.10% senior notes due December 2024
Debt Instrument [Line Items]
Unsecured debt	200		200
M&N US | M&N U.S. 7.50% senior notes due May 2014
Debt Instrument [Line Items]
Unsecured debt	0		411
Express-Platte | Express-Platte 6.09% senior secured notes due January 2020
Debt Instrument [Line Items]
Secured debt	110		110
Express-Platte | Express-Platte 7.39% subordinated secured notes due 2014 to 2019
Debt Instrument [Line Items]
Secured debt	74		104
Westcoast
Debt Instrument [Line Items]
Long-term debt principal (including current maturities)	2,542		2,505
Westcoast | 8.50% debentures due November 2015
Debt Instrument [Line Items]
Unsecured debt	108		118
Westcoast | 3.28% medium-term notes due January 2016
Debt Instrument [Line Items]
Unsecured debt	215		235
Westcoast | 8.50% debentures due September 2018
Debt Instrument [Line Items]
Unsecured debt	129		141
Westcoast | 5.60% medium-term notes due January 2019
Debt Instrument [Line Items]
Unsecured debt	258		282
Westcoast | 9.90% debentures due January 2020
Debt Instrument [Line Items]
Unsecured debt	86		94
Westcoast | 4.57% medium-term notes due July 2020
Debt Instrument [Line Items]
Unsecured debt	215		235
Westcoast | 3.88% medium-term notes due October 2021
Debt Instrument [Line Items]
Unsecured debt	129		142
Westcoast | 3.12% medium-term notes due December 2022
Debt Instrument [Line Items]
Unsecured debt	215		235
Westcoast | 3.43% medium-term notes due September 2024
Debt Instrument [Line Items]
Unsecured debt	301		0
Westcoast | 8.85% debentures due July 2025
Debt Instrument [Line Items]
Unsecured debt	129		142
Westcoast | 8.80% medium-term notes due November 2025
Debt Instrument [Line Items]
Unsecured debt	22		24
Westcoast | 7.30% debentures due December 2026
Debt Instrument [Line Items]
Unsecured debt	108		118
Westcoast | 6.75% medium-term notes due December 2027
Debt Instrument [Line Items]
Unsecured debt	129		141
Westcoast | 7.15% medium-term notes due March 2031
Debt Instrument [Line Items]
Unsecured debt	172		188
Westcoast | 4.79% medium-term notes due October 2041
Debt Instrument [Line Items]
Unsecured debt	129		141
Westcoast | Other
Debt Instrument [Line Items]
Unsecured debt	2		2
M&N Canada | M&N Canada 6.90% senior secured notes due 2014 to 2019
Debt Instrument [Line Items]
Secured debt	112		147
M&N Canada | M&N Canada 4.34% senior secured notes due 2014 to 2019
Debt Instrument [Line Items]
Secured debt	83		120
Union Gas
Debt Instrument [Line Items]
Long-term debt principal (including current maturities)	2,444		2,391
Union Gas | 7.90% debentures due February 2014
Debt Instrument [Line Items]
Unsecured debt	0		141
Union Gas | 11.50% debentures due August 2015
Debt Instrument [Line Items]
Unsecured debt	129		141
Union Gas | 4.64% medium-term notes due June 2016
Debt Instrument [Line Items]
Unsecured debt	172		188
Union Gas | 9.70% debentures due November 2017
Debt Instrument [Line Items]
Unsecured debt	108		118
Union Gas | 5.35% medium-term notes due April 2018
Debt Instrument [Line Items]
Unsecured debt	172		188
Union Gas | 8.75% debentures due August 2018
Debt Instrument [Line Items]
Unsecured debt	108		118
Union Gas | 8.65% senior debentures due October 2018
Debt Instrument [Line Items]
Unsecured debt	64		72
Union Gas | 2.76% medium-term notes due June 2021
Debt Instrument [Line Items]
Unsecured debt	172		0
Union Gas | 4.85% medium-term notes due April 2022
Debt Instrument [Line Items]
Unsecured debt	108		118
Union Gas | 3.79% medium-term notes due July 2023
Debt Instrument [Line Items]
Unsecured debt	215		235
Union Gas | 8.65% debentures due November 2025
Debt Instrument [Line Items]
Unsecured debt	108		118
Union Gas | 5.46% medium-term notes due September 2036
Debt Instrument [Line Items]
Unsecured debt	142		155
Union Gas | 6.05% medium-term notes due September 2038
Debt Instrument [Line Items]
Unsecured debt	258		282
Union Gas | 5.20% medium-term notes due July 2040
Debt Instrument [Line Items]
Unsecured debt	215		235
Union Gas | 4.88% medium-term notes due June 2041
Debt Instrument [Line Items]
Unsecured debt	258		282
Union Gas | 4.20% medium-term notes due June 2044
Debt Instrument [Line Items]
Unsecured debt	$215		$0
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.
[3]	As of December 31, 2014 and 2013, respectively, $5,264 million and $5,248 million of debt was denominated in Canadian dollars.

Debt_and_Credit_Facilities_Sum1

Debt and Credit Facilities - Summary of Debt and Related Terms (Notes) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Commercial paper weighted average life period	14 days	9 days
Short-term debt, weighted average interest rate	0.60%	0.60%
Canadian Dollars Denominated
Debt Instrument [Line Items]
Long-term debt	5,264	5,248
Spectra Energy Capital, LLC | 5.50% senior unsecured notes due March 2014
Debt Instrument [Line Items]
Unsecured debt	0	149
Debt instrument, interest rate, stated percentage	5.50%
Debt instrument, maturity date, description	Mar-14
Spectra Energy Capital, LLC | 5.67% senior unsecured notes due August 2014
Debt Instrument [Line Items]
Unsecured debt	0	408
Debt instrument, interest rate, stated percentage	5.67%
Debt instrument, maturity date, description	Aug-14
Spectra Energy Capital, LLC | 6.20% senior unsecured notes due April 2018
Debt Instrument [Line Items]
Unsecured debt	500	500
Debt instrument, interest rate, stated percentage	6.20%
Debt instrument, maturity date, description	Apr-18
Spectra Energy Capital, LLC | 6.75% senior unsecured notes due July 2018
Debt Instrument [Line Items]
Unsecured debt	150	150
Debt instrument, interest rate, stated percentage	6.75%
Debt instrument, maturity date, description	Jul-18
Spectra Energy Capital, LLC | Variable-rate senior unsecured term loan due November 2018
Debt Instrument [Line Items]
Unsecured debt	300	0
Debt instrument, maturity date, description	Nov-18
Spectra Energy Capital, LLC | 8.00% senior unsecured notes due October 2019
Debt Instrument [Line Items]
Unsecured debt	500	500
Debt instrument, interest rate, stated percentage	8.00%
Debt instrument, maturity date, description	Oct-19
Spectra Energy Capital, LLC | 5.65% senior unsecured notes due March 2020
Debt Instrument [Line Items]
Unsecured debt	300	300
Debt instrument, interest rate, stated percentage	5.65%
Debt instrument, maturity date, description	Mar-20
Spectra Energy Capital, LLC | 3.30% senior unsecured notes due March 2023
Debt Instrument [Line Items]
Unsecured debt	650	650
Debt instrument, interest rate, stated percentage	3.30%
Debt instrument, maturity date, description	Mar-23
Spectra Energy Capital, LLC | 6.75% senior unsecured notes due February 2032
Debt Instrument [Line Items]
Unsecured debt	240	240
Debt instrument, interest rate, stated percentage	6.75%
Debt instrument, maturity date, description	Feb-32
Spectra Energy Capital, LLC | 7.50% senior unsecured notes due September 2038
Debt Instrument [Line Items]
Unsecured debt	250	250
Debt instrument, interest rate, stated percentage	7.50%
Debt instrument, maturity date, description	Sep-38
SEP | SEP 2.95% senior unsecured notes due June 2016
Debt Instrument [Line Items]
Unsecured debt	250	250
Debt instrument, interest rate, stated percentage	2.95%
Debt instrument, maturity date, description	Jun-16
SEP | SEP 2.95% senior unsecured notes due September 2018
Debt Instrument [Line Items]
Unsecured debt	500	500
Debt instrument, interest rate, stated percentage	2.95%
Debt instrument, maturity date, description	Sep-18
SEP | SEP Variable-rate senior unsecured term loan due November 2018
Debt Instrument [Line Items]
Unsecured debt	400	400
Debt instrument, maturity date, description	Nov-18
SEP | SEP 4.60% senior unsecured notes due June 2021
Debt Instrument [Line Items]
Unsecured debt	250	250
Debt instrument, interest rate, stated percentage	4.60%
Debt instrument, maturity date, description	Jun-21
SEP | SEP 4.75% senior unsecured notes due March 2024
Debt Instrument [Line Items]
Unsecured debt	1,000	1,000
Debt instrument, interest rate, stated percentage	4.75%
Debt instrument, maturity date, description	Mar-24
SEP | SEP 5.95% senior unsecured notes due September 2043
Debt Instrument [Line Items]
Unsecured debt	400	400
Debt instrument, interest rate, stated percentage	5.95%
Debt instrument, maturity date, description	Sep-43
Texas Eastern | Texas Eastern 6.00% senior unsecured notes due September 2017
Debt Instrument [Line Items]
Unsecured debt	400	400
Debt instrument, interest rate, stated percentage	6.00%
Debt instrument, maturity date, description	Sep-17
Texas Eastern | Texas Eastern 4.13% senior unsecured notes due December 2020
Debt Instrument [Line Items]
Unsecured debt	300	300
Debt instrument, interest rate, stated percentage	4.13%
Debt instrument, maturity date, description	Dec-20
Texas Eastern | Texas Eastern 2.80% senior unsecured notes due October 2022
Debt Instrument [Line Items]
Unsecured debt	500	500
Debt instrument, interest rate, stated percentage	2.80%
Debt instrument, maturity date, description	Oct-22
Texas Eastern | Texas Eastern 7.00% senior unsecured notes due July 2032
Debt Instrument [Line Items]
Unsecured debt	450	450
Debt instrument, interest rate, stated percentage	7.00%
Debt instrument, maturity date, description	Jul-32
Algonquin | Algonquin 3.51% senior notes due July 2024
Debt Instrument [Line Items]
Unsecured debt	350	350
Debt instrument, interest rate, stated percentage	3.51%
Debt instrument, maturity date, description	Jul-24
East Tennessee Natural Gas, LLC | East Tennessee Natural Gas, LLC 3.10% senior notes due December 2024
Debt Instrument [Line Items]
Unsecured debt	200	200
Debt instrument, interest rate, stated percentage	3.10%
Debt instrument, maturity date, description	Dec-24
M&N US | M&N U.S. 7.50% senior notes due May 2014
Debt Instrument [Line Items]
Unsecured debt	0	411
Debt instrument, interest rate, stated percentage	7.50%
Debt instrument, maturity date, description	May-14
Express-Platte | Express-Platte 6.09% senior secured notes due January 2020
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	6.09%
Debt instrument, maturity date, description	Jan-20
Express-Platte | Express-Platte 7.39% subordinated secured notes due 2014 to 2019
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	7.39%
Debt instrument, maturity date, description	2014 to 2019
Westcoast | 8.50% debentures due November 2015
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	8.50%
Debt instrument, maturity date, description	Nov-15
Westcoast | 3.28% medium-term notes due January 2016
Debt Instrument [Line Items]
Unsecured debt	215	235
Debt instrument, interest rate, stated percentage	3.28%
Debt instrument, maturity date, description	Jan-16
Westcoast | 8.50% debentures due September 2018
Debt Instrument [Line Items]
Unsecured debt	129	141
Debt instrument, interest rate, stated percentage	8.50%
Debt instrument, maturity date, description	Sep-18
Westcoast | 5.60% medium-term notes due January 2019
Debt Instrument [Line Items]
Unsecured debt	258	282
Debt instrument, interest rate, stated percentage	5.60%
Debt instrument, maturity date, description	Jan-19
Westcoast | 9.90% debentures due January 2020
Debt Instrument [Line Items]
Unsecured debt	86	94
Debt instrument, interest rate, stated percentage	9.90%
Debt instrument, maturity date, description	Jan-20
Westcoast | 4.57% medium-term notes due July 2020
Debt Instrument [Line Items]
Unsecured debt	215	235
Debt instrument, interest rate, stated percentage	4.57%
Debt instrument, maturity date, description	Jul-20
Westcoast | 3.88% medium-term notes due October 2021
Debt Instrument [Line Items]
Unsecured debt	129	142
Debt instrument, interest rate, stated percentage	3.88%
Debt instrument, maturity date, description	Oct-21
Westcoast | 3.12% medium-term notes due December 2022
Debt Instrument [Line Items]
Unsecured debt	215	235
Debt instrument, interest rate, stated percentage	3.12%
Debt instrument, maturity date, description	Dec-22
Westcoast | 3.43% medium-term notes due September 2024
Debt Instrument [Line Items]
Unsecured debt	301	0
Debt instrument, interest rate, stated percentage	3.43%
Debt instrument, maturity date, description	Sep-24
Westcoast | 8.85% debentures due July 2025
Debt Instrument [Line Items]
Unsecured debt	129	142
Debt instrument, interest rate, stated percentage	8.85%
Debt instrument, maturity date, description	Jul-25
Westcoast | 8.80% medium-term notes due November 2025
Debt Instrument [Line Items]
Unsecured debt	22	24
Debt instrument, interest rate, stated percentage	8.80%
Debt instrument, maturity date, description	Nov-25
Westcoast | 7.30% debentures due December 2026
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	7.30%
Debt instrument, maturity date, description	Dec-26
Westcoast | 6.75% medium-term notes due December 2027
Debt Instrument [Line Items]
Unsecured debt	129	141
Debt instrument, interest rate, stated percentage	6.75%
Debt instrument, maturity date, description	Dec-27
Westcoast | 7.15% medium-term notes due March 2031
Debt Instrument [Line Items]
Unsecured debt	172	188
Debt instrument, interest rate, stated percentage	7.15%
Debt instrument, maturity date, description	Mar-31
Westcoast | 4.79% medium-term notes due October 2041
Debt Instrument [Line Items]
Unsecured debt	129	141
Debt instrument, interest rate, stated percentage	4.79%
Debt instrument, maturity date, description	Oct-41
M&N Canada | M&N Canada 6.90% senior secured notes due 2014 to 2019
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	6.90%
Debt instrument, maturity date, description	2014 to 2019
M&N Canada | M&N Canada 4.34% senior secured notes due 2014 to 2019
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	4.34%
Debt instrument, maturity date, description	2014 to 2019
Union Gas | 7.90% debentures due February 2014
Debt Instrument [Line Items]
Unsecured debt	0	141
Debt instrument, interest rate, stated percentage	7.90%
Debt instrument, maturity date, description	Feb-14
Union Gas | 11.50% debentures due August 2015
Debt Instrument [Line Items]
Unsecured debt	129	141
Debt instrument, interest rate, stated percentage	11.50%
Debt instrument, maturity date, description	Aug-15
Union Gas | 4.64% medium-term notes due June 2016
Debt Instrument [Line Items]
Unsecured debt	172	188
Debt instrument, interest rate, stated percentage	4.64%
Debt instrument, maturity date, description	Jun-16
Union Gas | 9.70% debentures due November 2017
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	9.70%
Debt instrument, maturity date, description	Nov-17
Union Gas | 5.35% medium-term notes due April 2018
Debt Instrument [Line Items]
Unsecured debt	172	188
Debt instrument, interest rate, stated percentage	5.35%
Debt instrument, maturity date, description	Apr-18
Union Gas | 8.75% debentures due August 2018
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	8.75%
Debt instrument, maturity date, description	Aug-18
Union Gas | 8.65% senior debentures due October 2018
Debt Instrument [Line Items]
Unsecured debt	64	72
Debt instrument, interest rate, stated percentage	8.65%
Debt instrument, maturity date, description	Oct-18
Union Gas | 2.76% medium-term notes due June 2021
Debt Instrument [Line Items]
Unsecured debt	172	0
Debt instrument, interest rate, stated percentage	2.76%
Debt instrument, maturity date, description	Jun-21
Union Gas | 4.85% medium-term notes due April 2022
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	4.85%
Debt instrument, maturity date, description	Apr-22
Union Gas | 3.79% medium-term notes due July 2023
Debt Instrument [Line Items]
Unsecured debt	215	235
Debt instrument, interest rate, stated percentage	3.79%
Debt instrument, maturity date, description	Jul-23
Union Gas | 8.65% debentures due November 2025
Debt Instrument [Line Items]
Unsecured debt	108	118
Debt instrument, interest rate, stated percentage	8.65%
Debt instrument, maturity date, description	Nov-25
Union Gas | 5.46% medium-term notes due September 2036
Debt Instrument [Line Items]
Unsecured debt	142	155
Debt instrument, interest rate, stated percentage	5.46%
Debt instrument, maturity date, description	Sep-36
Union Gas | 6.05% medium-term notes due September 2038
Debt Instrument [Line Items]
Unsecured debt	258	282
Debt instrument, interest rate, stated percentage	6.05%
Debt instrument, maturity date, description	Sep-38
Union Gas | 5.20% medium-term notes due July 2040
Debt Instrument [Line Items]
Unsecured debt	215	235
Debt instrument, interest rate, stated percentage	5.20%
Debt instrument, maturity date, description	Jul-40
Union Gas | 4.88% medium-term notes due June 2041
Debt Instrument [Line Items]
Unsecured debt	258	282
Debt instrument, interest rate, stated percentage	4.88%
Debt instrument, maturity date, description	Jun-41
Union Gas | 4.20% medium-term notes due June 2044
Debt Instrument [Line Items]
Unsecured debt	215	0
Debt instrument, interest rate, stated percentage	4.20%
Debt instrument, maturity date, description	Jun-44

Debt_and_Credit_Facilities_Ann

Debt and Credit Facilities - Annual Maturities (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Debt Disclosure [Abstract]
2015	$327
2016	713
2017	563
2018	2,353
2019	787
Thereafter	8,353
Total long-term debt, including current maturities	$13,096	[1]
[1]	Excludes commercial paper of $1,583 million. Includes capital leases of $24 million and other non-principal amounts of $12 million.

Debt_and_Credit_Facilities_Ann1

Debt and Credit Facilities - Annual Maturities (Notes) (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Debt Disclosure [Abstract]
Commercial paper	$1,583	[1],[2]	$1,032	[1],[2]
Capital Leases	24		0
Debt Instrument Total Other Nonprincipal Amounts	$12		$17
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.

Debt_and_Credit_Facilities_Ava

Debt and Credit Facilities - Available Credit Facilities and Restrictive Debt Covenants (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013
Line of Credit Facility [Line Items]
Total Credit Facilities Capacity	$3,774,000,000
Commercial Paper	1,583,000,000	[1],[2]	1,032,000,000	[1],[2]
Available Credit Facilities Capacity	2,191,000,000
Spectra Energy Capital, LLC
Line of Credit Facility [Line Items]
Commercial Paper	398,000,000		344,000,000
Spectra Energy Capital, LLC | Multi Year Syndicated
Line of Credit Facility [Line Items]
Expiration Date	2019	[3]
Total Credit Facilities Capacity	1,000,000,000	[3]
Commercial Paper	398,000,000	[3]
Available Credit Facilities Capacity	602,000,000	[3]
SEP | Multi Year Syndicated
Line of Credit Facility [Line Items]
Expiration Date	2019	[4]
Total Credit Facilities Capacity	2,000,000,000	[4]
Commercial Paper	907,000,000	[4]
Available Credit Facilities Capacity	1,093,000,000	[4]
Westcoast | Multi Year Syndicated
Line of Credit Facility [Line Items]
Expiration Date	2019	[5]
Total Credit Facilities Capacity	344,000,000	[5]
Commercial Paper	46,000,000	[5]
Available Credit Facilities Capacity	298,000,000	[5]
Union Gas | Multi Year Syndicated
Line of Credit Facility [Line Items]
Expiration Date	2019	[6]
Total Credit Facilities Capacity	430,000,000	[6]
Commercial Paper	232,000,000	[6]
Available Credit Facilities Capacity	$198,000,000	[6]
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.
[3]	Revolving credit facility contains a covenant requiring the Spectra Energy Corp consolidated debt-to-total capitalization ratio, as defined in the agreement, to not exceed 65%. Per the terms of the agreement, collateralized debt is excluded from the calculation of the ratio. This ratio was 58% at December 31, 2014.
[4]	Revolving credit facility contains a covenant that requires SEP 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 December 31, 2014, this ratio was 3.7 to 1.
[5]	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 400 million Canadian dollars and contains a covenant that requires the Westcoast non-consolidated debt-to-total capitalization ratio to not exceed 75%. The ratio was 35% at December 31, 2014.
[6]	U.S. dollar equivalent at December 31, 2014. The revolving credit facility is 500 million Canadian dollars and contains a covenant that requires the Union Gas debt-to-total capitalization ratio to not exceed 75% and a provision which requires Union Gas to repay all borrowings under the facility for a period of two days during the second quarter of each year. The ratio was 68% at December 31, 2014.

Debt_and_Credit_Facilities_Ava1

Debt and Credit Facilities - Available Credit Facilities and Restrictive Debt Covenants (Notes) (Detail)	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014
	USD ($)	Spectra Energy Capital, LLC	Spectra Energy Capital, LLC	SEP	Westcoast	Westcoast	Union Gas	Union Gas
		Covenant Requirement	Covenant Requirement	Covenant Requirement	Covenant Requirement	Covenant Requirement	Covenant Requirement	Covenant Requirement
			Maximum		CAD	Maximum	CAD	Maximum
Line of Credit Facility [Line Items]
Debt-to-total defined capitalization ratio		58.00%	65.00%
Total consolidated indebtedness-consolidated EBITDA				5
Current total consolidated indebtedness-consolidated EBITDA				3.7
Line of credit facility, maximum borrowing capacity	$3,774,000,000				400,000,000		500,000,000
Non-consolidated debt to total capitalization ratio					35.00%	75.00%	68.00%	75.00%

Debt_and_Credit_Facilities_Add

Debt and Credit Facilities - Additional Information (Detail)	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2014
	USD ($)	Floating Rate Debt	Floating Rate Debt		Spectra Energy Capital, LLC	Spectra Energy Capital, LLC	Spectra Energy Capital, LLC	Westcoast Energy Inc.	Union Gas Limited
		USD ($)	USD ($)		USD ($)	Covenant Requirement	Covenant Requirement	Covenant Requirement	Covenant Requirement
							Maximum	CAD	CAD
Debt Instrument [Line Items]
Secured debt	$379,000,000
Long-term debt		2,283,000,000	1,432,000,000	[1],[2]
Debt, Weighted Average Interest Rate		0.80%	0.80%
Line of credit facility, maximum borrowing capacity	3,774,000,000							400,000,000	500,000,000
Debt-to-total defined capitalization ratio						58.00%	65.00%
Equity (net assets) restricted					$7,800,000,000
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.

Preferred_Stock_of_Subsidiarie1

Preferred Stock of Subsidiaries (Details)	Dec. 31, 2014
Equity [Abstract]
Percentage of redeemable preferred shares at the option of Westcoast and Union	100.00%

Fair_Value_Measurements_Assets

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis with Fair Value Hierarchy Levels (Detail) (Fair Value, Measurements, Recurring, USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	$211	$91
Fair Value Liabilities		9
Corporate Debt Securities | Cash and Cash Equivalents
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	85	49
Corporate Debt Securities | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	3	7
Corporate Debt Securities | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	20	11
Commodity Contract | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	57
Commodity Contract | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	21
Interest Rate Swap | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	2	8
Interest Rate Swap | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	22	15
Interest Rate Swap | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		6
Money Market Funds | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	1	1
Natural Gas Purchase Contract | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		3
Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	1	1
Fair Value Liabilities		0
Level 1 | Corporate Debt Securities | Cash and Cash Equivalents
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 1 | Corporate Debt Securities | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 1 | Corporate Debt Securities | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 1 | Commodity Contract | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0
Level 1 | Commodity Contract | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0
Level 1 | Interest Rate Swap | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 1 | Interest Rate Swap | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 1 | Interest Rate Swap | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		0
Level 1 | Money Market Funds | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	1	1
Level 1 | Natural Gas Purchase Contract | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		0
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	132	90
Fair Value Liabilities		6
Level 2 | Corporate Debt Securities | Cash and Cash Equivalents
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	85	49
Level 2 | Corporate Debt Securities | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	3	7
Level 2 | Corporate Debt Securities | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	20	11
Level 2 | Commodity Contract | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0
Level 2 | Commodity Contract | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0
Level 2 | Interest Rate Swap | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	2	8
Level 2 | Interest Rate Swap | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	22	15
Level 2 | Interest Rate Swap | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		6
Level 2 | Money Market Funds | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 2 | Natural Gas Purchase Contract | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		0
Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	78	0
Fair Value Liabilities		3
Level 3 | Corporate Debt Securities | Cash and Cash Equivalents
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Corporate Debt Securities | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Corporate Debt Securities | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Commodity Contract | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	57
Level 3 | Commodity Contract | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	21
Level 3 | Interest Rate Swap | Current Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Interest Rate Swap | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Interest Rate Swap | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		0
Level 3 | Money Market Funds | Investments and Other Assets - Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Assets	0	0
Level 3 | Natural Gas Purchase Contract | Deferred Credits and Other Liabilities - Regulatory and Other
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value Liabilities		$3

Fair_Value_Measurements_Change

Fair Value Measurements - Changes in Level 3 Assets and Liabilities that are Measured at Fair Value on Recurring Basis using Significant Unobservable Inputs (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Financial Instruments, Liabilities
Total gains (losses):
Included in earnings	$91	($3)
Included in other comprehensive income	5	8
Settlements	-15	1
Fair value, end of period		-3	-9
Total gains (losses) for the period included in earnings (or changes in net assets) attributable to the change in unrealized gains or losses relating to assets and liabilities held at the end of the period		-2
Derivative Financial Instruments, Assets
Total gains (losses):
Fair value, end of period	78
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Assets	$56

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value of Financial Instruments Recorded and Carried at Book Value (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Book Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, noncurrent	$71	[1]	$71	[1]
Long-term debt, including current maturities	13,060	[2]	13,668	[2]
Approximate Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, noncurrent	71	[1]	71	[1]
Long-term debt, including current maturities	$14,446	[2]	$14,701	[2]
[1]	Included within Investments in and Loans to Unconsolidated Affiliates.
[2]	Excludes capital leases, unamortized items and fair value hedge carrying value adjustments.

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Details) (Commodity Contract, USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015
	gal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	163,000,000
Scenario, Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Servicing Asset at Fair Value, Description of Other Changes that Affect Balance		$0.10
Servicing Asset at Fair Value, Changes in Fair Value Resulting from Changes in Valuation Inputs or Changes in Assumptions		$16,000,000

Risk_Management_and_Hedging_Ac2

Risk Management and Hedging Activities - Derivative Portfolio Carrying Value (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative [Line Items]
Maturities in 2015	$59
Maturities in 2016	19
Maturities in 2017	4
Maturities in 2018 and Thereafter	20
Total Carrying Value	102
Hedging
Derivative [Line Items]
Maturities in 2015	0
Maturities in 2016	0
Maturities in 2017	2
Maturities in 2018 and Thereafter	20
Total Carrying Value	22
Undesignated
Derivative [Line Items]
Maturities in 2015	59
Maturities in 2016	19
Maturities in 2017	2
Maturities in 2018 and Thereafter	0
Total Carrying Value	80
Interest Rate Swap | Hedging
Derivative [Line Items]
Maturities in 2015	0
Maturities in 2016	0
Maturities in 2017	2
Maturities in 2018 and Thereafter	20
Total Carrying Value	22
Interest Rate Swap | Undesignated
Derivative [Line Items]
Maturities in 2015	2
Maturities in 2016	0
Maturities in 2017	0
Total Carrying Value	2
Commodity Contract | Undesignated
Derivative [Line Items]
Maturities in 2015	57
Maturities in 2016	19
Maturities in 2017	2
Maturities in 2018 and Thereafter	0
Total Carrying Value	$78

Risk_Management_and_Hedging_Ac3

Risk Management and Hedging Activities - Derivative Assets And Liabilities Offsetting Information (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Interest Rate Swap
Derivative Assets And Liabilities Offsetting Table Text Block [Line Items]
Gross Amounts Presented in the Consolidated Balance Sheets, Assets	$24	$23
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	0	3
Net Amount, Assets	24	20
Gross Amounts Presented in the Consolidated Balance Sheets, Liabilities	0	6
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	0	3
Net Amount, Liabilities	0	3
Commodity Contract
Derivative Assets And Liabilities Offsetting Table Text Block [Line Items]
Gross Amounts Presented in the Consolidated Balance Sheets, Assets	169
Derivative Asset, Fair Value, Amount Offset Against Collateral	91
Net Amount, Assets	78
Gross Amounts Presented in the Consolidated Balance Sheets, Liabilities	91
Net Amount, Liabilities	0
Derivative Liability, Fair Value, Amount Offset Against Collateral	$91

Risk_Management_and_Hedging_Ac4

Risk Management and Hedging Activities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
	gal
Commodity Contract
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	163,000,000
Pay Floating Receive Fixed Swaps
Derivative [Line Items]
Derivative, Notional Amount	1,208

Risk_Management_and_Hedging_Ac5

Risk Management and Hedging Activities - Commodity derivative impact (Details) (Commodity Contract, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Commodity Contract
Commodity derivative impact [Line Items]
Sales of natural gas liquids	$93	$0	$0

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Commitments and Contingencies Disclosure [Abstract]
Accruals related to extended environmental-related activities included in Deferred Credits and Other Liabilities-Regulatory and Other on the Consolidated Balance Sheet	$10	$11
Rental expense for operating leases included in Operating, Maintenance and Other on the Consolidated Statements of Operations	$38	$38	$38

Commitments_and_Contingencies_2

Commitments and Contingencies - Summary of Future Minimum Lease Payments Under Operating Leases (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]
2015	$50
2016	44
2017	42
2018	36
2019	32
Thereafter	148
Total future minimum lease payments	$352

Guarantees_and_Indemnification1

Guarantees and Indemnifications - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Duke Energy
Guarantor Obligations [Line Items]
Maximum potential amount of future payments required to make under performance guarantees	$406
Duke Energy | Guarantees Expire in 2028
Guarantor Obligations [Line Items]
Maximum potential amount of future payments required to make under performance guarantees	$201
Guarantee expiration year	2028
Fluor Enterprises
Guarantor Obligations [Line Items]
Percentage of ownership	50.00%
Westcoast Energy Inc.
Guarantor Obligations [Line Items]
Percentage of ownership interests	100.00%

Common_Stock_Issuance_Addition

Common Stock Issuance - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Equity [Abstract]
Spectra Energy common stock issuance (in shares)			14.7
Spectra Energy common stock issuance	$0	$0	$382

Effects_of_Changes_in_Noncontr2

Effects of Changes in Noncontrolling Interests Ownership (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Noncontrolling Interest [Abstract]
Net income — controlling interests	$316	$201	$146	$419	$236	$263	$199	$340	$1,082		$1,038		$940
Increase in additional paid-in capital resulting from issuances of SEP units									49	[1]	42	[1]	26	[1]
Total net income — controlling interests and changes in equity — controlling interests									$1,131		$1,080		$966
[1]	See Note 2 for further discussion.

StockBased_Compensation_Additi

Stock-Based Compensation - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of common stock awarded (in shares)	40,000,000
Tax benefit in income from continuing operations associated with recorded expense	$7	$8	$8
Recognized tax benefits from stock-based compensation cost in additional paid in capital	3	5	16
Restricted, performance and phantom stock awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based awards granted percentage vested	100.00%
Stock-based awards vesting period	3 years
Stock options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based awards term	10 years
Total intrinsic value of options exercised	6	21	11
Cash received from options exercised	11	43	17
Stock options | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based awards vesting period	3 years
Performance awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based awards vesting period	3 years
Granted (in shares)	557,100	356,600	306,800
Fair value of equity classified awards granted	26	13	13
Fair value of liability-classified awards granted		13	5
Share based compensation arrangement by share based payment award, fair value assumptions, yield, period	3 years
Total fair value of shares vested	20	19	12
Future compensation cost related to stock awards expected to be recognized	26
Performance awards | Single Subsidiary EBITDA
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested and outstanding performance awards granted containing EBITDA	12,900
Performance awards | Total shareholder return
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested and outstanding performance awards granted containing EBITDA	1,761,967
Performance awards | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected future compensation cost related to stock awards, weighted-average period of recognition	1 year
Phantom Stock Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based awards vesting period	3 years
Granted (in shares)	454,000
Total fair value of shares vested	11	14	11
Future compensation cost related to stock awards expected to be recognized	18
Phantom Stock Awards | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected future compensation cost related to stock awards, weighted-average period of recognition	2 years
Liability-classified award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)	353,000	343,700	306,800
Fair value of equity classified awards granted	13
Equity-classified awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)	101,500	474,500	440,200
Fair value of equity classified awards granted	$4	$14	$14

StockBased_Compensation_Compon

Stock-Based Compensation - Components of Pre-Tax Stock Based Compensation Expense in Continuing Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre tax stock based compensation	$27	$46	$29
Phantom stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre tax stock based compensation	14	13	12
Performance awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre tax stock based compensation	$13	$33	$17

StockBased_Compensation_Stock_

Stock-Based Compensation - Stock Awards Activity (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Performance Awards
Units
Outstanding at beginning of period (in shares)	1,936,000
Granted (in shares)	557,100	356,600	306,800
Vested (in shares)	-601,000
Forfeited (in shares)	-117,000
Outstanding at end of period (in shares)	1,775,000	1,936,000
Awards expected to vest (in shares)	1,709,000
Weighted Average Grant Date Fair Value
Outstanding at beginning of period (in usd per share)	$38
Granted (in usd per share)	$46
Vested (in usd per share)	$33
Forfeited (in usd per share)	$38
Outstanding at end of period (in usd per share)	$35	$38
Awards expected to vest (in usd per share)	$35
Phantom Stock Awards
Units
Outstanding at beginning of period (in shares)	1,302,000
Granted (in shares)	454,000
Vested (in shares)	-431,000
Forfeited (in shares)	-44,000
Outstanding at end of period (in shares)	1,281,000
Awards expected to vest (in shares)	1,229,000
Weighted Average Grant Date Fair Value
Outstanding at beginning of period (in usd per share)	$29
Granted (in usd per share)	$38
Vested (in usd per share)	$26
Forfeited (in usd per share)	$33
Outstanding at end of period (in usd per share)	$33
Awards expected to vest (in usd per share)	$33

StockBased_Compensation_Weight

Stock-Based Compensation - Weighted Average Assumptions for Performance Awards (Detail) (Performance Awards)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Performance Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free rate of return	0.70%	0.40%	0.40%
Expected life	3 years	3 years	3 years
Expected volatility—Spectra Energy	20.00%	21.00%	25.00%
Expected volatility, Minimum-peer group	14.00%	13.00%	16.00%
Expected volatility, Maximum-peer group	32.00%	33.00%	42.00%
Market index (a)		16.00%	20.00%

StockBased_Compensation_Stock_1

Stock-Based Compensation - Stock Option Activity (Detail) (USD $)	12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Options
Outstanding at beginning of period (in shares)	1,532
Exercised (in shares)	-430
Forfeited or expired (in shares)	0
Outstanding at end of period (in shares)	1,102	1,532
Exercisable at end of period (in shares)	1,102
Weighted- Average Exercise Price
Outstanding at beginning of period (in usd per share)	$25
Exercised (in usd per share)	$25
Forfeited or expired (in usd per share)	$0
Outstanding at end of period (in usd per share)	$25	$25
Exercisable at end of period (in usd per share)	$25
Weighted- Average Remaining Life
Outstanding at beginning of period	2 years	2 years 11 months
Outstanding at end of period	2 years	2 years 11 months
Exercisable at end of period	2 years
Aggregate Intrinsic Value
Outstanding at beginning of period	$16
Outstanding at end of period	12	16
Exercisable at end of period	$12

Employee_Benefit_Plans_Additio

Employee Benefit Plans - Additional Information (Detail) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2013
Level 1
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Money Market Funds Fair Value Disclosure	$17	$18
Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	-4	-5
Defined Benefit Plan, Benefit Obligation	133	133	149
Defined Benefit Plan, Contributions by Employer	4	5
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	5
Fair values of plan assets	0	0	0
U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	0	0
Defined Benefit Plan, Benefit Obligation	172	184	202
Defined Benefit Plan, Contributions by Employer	14	13
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	10
Average Remaining Service Period Of Active Employees	12 years
Defined Benefit Plan Periods Of Changes In Fair Value Of Plan Asset Used To Determine Market Related Value	5 years
Fair values of plan assets	92	87	79
U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	0	1
Defined Benefit Plan, Future Amortization of Gain (Loss)	-10
Defined Benefit Plan, Benefit Obligation	586	575	610
Defined Benefit Plan, Contributions by Employer	21	22	26
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	22
Average Remaining Service Period Of Active Employees	10 years
Defined Benefit Plan Periods Of Changes In Fair Value Of Plan Asset Used To Determine Market Related Value	5 years
Defined Benefit Plan, Accumulated Benefit Obligation	567	547
Fair values of plan assets	551	531	483
Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	6	7
Defined Benefit Plan, Future Amortization of Gain (Loss)	-27
Defined Benefit Plan, Benefit Obligation	1,202	1,131	1,262
Defined Benefit Plan, Contributions by Employer	36	80	87
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	30
Defined Benefit Plan Periods Of Changes In Fair Value Of Plan Asset Used To Determine Market Related Value	3 years
Defined Benefit Plan, Accumulated Benefit Obligation	1,123	1,059
Fair values of plan assets	1,050	1,040	961
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	1
Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost Recognized		13
U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost Recognized		14	12
Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Discretionary Contribution Amount	9		9	9
Defined Contribution Plan Estimated Future Employer Contributions In Next Fiscal Year	10
Qualified pension plans | Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Average Remaining Service Period Of Active Employees	10 years
Nonqualifed and Unfunded Pension Plans | U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Benefit Obligation	22	22
Nonqualifed and Unfunded Pension Plans | Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Benefit Obligation	117
Plans with accumulated benefit obligations in excess of plan assets | Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation	388
Defined Benefit Plan, Accumulated Benefit Obligation	360
Fair values of plan assets	239
Accumulated Other Comprehensive Income (Loss) | Canada
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	1
Canada | U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan Contribution Rates As Percentage Of Employees Earnings	5.00%
Defined Contribution Plan, Cost Recognized	13		12
UNITED STATES | U.S.
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan Contribution Rates As Percentage Of Employees Earnings	6.00%
Defined Contribution Plan, Cost Recognized	$15

Employee_Benefit_Plans_Change_

Employee Benefit Plans - Change in Projected Benefit Obligation and Change in Fair Value of Plan Assets (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
U.S.
Change in Projected Benefit Obligation
Projected benefit obligation, beginning balance	$575		$610
Transfers in	0		0
Service cost	19		19
Interest cost	24		21		23
Actuarial loss (gain)	13		-36
Participant contributions	0		0
Benefits paid	-45		-39
Foreign currency translation effect	0		0
Projected benefit obligation, ending balance	586		575		610
Change in Fair Value of Plan Assets
Plan assets, beginning of period	531		483
Transfers in	0		0
Actual return on plan assets	44		65
Benefits paid	-45		-39
Employer contributions	21		22		26
Plan participants’ contributions	0		0
Foreign currency translation effect	0		0
Plan assets, end of period	551		531		483
Net amount recognized	-35	[1]	-44	[1]
Accumulated Benefit Obligation	567		547
Defined Benefit Plan, Current Liabilities - Other	-2		-2
Defined Benefit Plan, Deferred Credits and Other Liabilities - Regulatory and Other	-33		-42
Defined Benefit Plan, Other Assets - Other	0		0
Defined Contribution Plan, Cost Recognized	-35		-44
Canada
Change in Projected Benefit Obligation
Projected benefit obligation, beginning balance	1,131		1,262
Transfers in	0		6
Service cost	25		33
Interest cost	52		50		50
Actuarial loss (gain)	143		-92
Participant contributions	5		5
Benefits paid	-49		-51
Foreign currency translation effect	-105		-82
Projected benefit obligation, ending balance	1,202		1,131		1,262
Change in Fair Value of Plan Assets
Plan assets, beginning of period	1,040		961
Transfers in	0		3
Actual return on plan assets	115		110
Benefits paid	-49		-51
Employer contributions	36		80		87
Plan participants’ contributions	5		5
Expected non-investment expenses	-3
Foreign currency translation effect	-94		-68
Plan assets, end of period	1,050		1,040		961
Net amount recognized	-152	[1]	-91
Accumulated Benefit Obligation	1,123		1,059
Defined Benefit Plan, Current Liabilities - Other	-6		-6
Defined Benefit Plan, Deferred Credits and Other Liabilities - Regulatory and Other	-165		-130
Defined Benefit Plan, Other Assets - Other	19		45
Defined Contribution Plan, Cost Recognized	($152)		($91)
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlZDAxNDIxYzllMzRkYThhMjhkNDRlNWRhYTk4Y2Q4fFRleHRTZWxlY3Rpb246MkU3NTk0QjQ4MjIyNkI4NTYxODYyQjVERUIxRDBBMDYM}

Employee_Benefit_Plans_Amounts

Employee Benefit Plans - Amounts Recognized in Accumulated Other Comprehensive Income (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
U.S.
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	$141	$145
Prior service cost	0	1
Total amount recognized in AOCI	141	146
Canada
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss	345	275
Prior service cost	6	7
Total amount recognized in AOCI	$351	$282

Employee_Benefit_Plans_Compone

Employee Benefit Plans - Components of Net Periodic Pension Cost (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
U.S.
Net Periodic Pension Cost
Defined Benefit Plan, Other Costs	$19	$19	$17
Interest cost on projected benefit obligation	24	21	23
Expected return on plan assets	-39	-33	-33
Amortization of prior service cost	0	0	0
Amortization of loss	13	20	15
Net periodic other post-retirement benefit cost	17	27	22
Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	8	-69	33
Amortization of actuarial loss	-13	-20	-15
Amortization of prior service credit	0	0	0
Total recognized in other comprehensive income	-5	-89	18
Total Recognized in Net Periodic Pension Cost and Other Comprehensive Income	12	-62	40
Canada
Net Periodic Pension Cost
Defined Benefit Plan, Other Costs	29	33	30
Interest cost on projected benefit obligation	52	50	50
Expected return on plan assets	-69	-66	-61
Amortization of prior service cost	2	2	2
Amortization of loss	22	35	36
Net periodic other post-retirement benefit cost	36	54	57
Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	93	-133	44
Amortization of actuarial loss	-22	-35	-36
Amortization of prior service credit	-2	-2	-2
Total recognized in other comprehensive income	69	-170	6
Total Recognized in Net Periodic Pension Cost and Other Comprehensive Income	$105	($116)	$63

Employee_Benefit_Plans_Assumpt

Employee Benefit Plans - Assumptions Used for Pension Benefits Accounting (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
U.S.
Benefit Obligations
Discount rate	4.10%	4.31%	3.55%
Salary increase	4.00%	4.61%	4.61%
Net Periodic Benefit Cost
Discount rate	4.31%	3.55%	4.17%
Salary increase	4.61%	4.61%	4.61%
Expected long-term rate of return on plan assets	8.00%	7.40%	7.40%
Canada
Benefit Obligations
Discount rate	4.00%	4.81%	4.15%
Salary increase	3.25%	3.25%	3.25%
Net Periodic Benefit Cost
Discount rate	4.81%	4.15%	4.30%
Salary increase	3.25%	3.25%	3.25%
Expected long-term rate of return on plan assets	7.40%	7.10%	7.10%

Employee_Benefit_Plans_Qualifi

Employee Benefit Plans - Qualified Pension Plan Assets (Detail) (Qualified pension plans)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
U.S.
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	100.00%
Plan Asset Allocations	100.00%	100.00%
U.S. | U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	30.00%
Plan Asset Allocations	31.00%	31.00%
U.S. | Canadian equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	0.00%
Plan Asset Allocations	0.00%	0.00%
U.S. | Other Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	14.00%
Plan Asset Allocations	11.00%	14.00%
U.S. | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	46.00%
Plan Asset Allocations	48.00%	45.00%
U.S. | Other Investments
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	10.00%
Plan Asset Allocations	10.00%	10.00%
Canada
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	100.00%
Plan Asset Allocations	100.00%	100.00%
Canada | U.S. equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	17.00%
Plan Asset Allocations	17.00%	18.00%
Canada | Canadian equity securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	25.00%
Plan Asset Allocations	25.00%	26.00%
Canada | Other Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	13.00%
Plan Asset Allocations	13.00%	13.00%
Canada | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	45.00%
Plan Asset Allocations	45.00%	43.00%
Canada | Other Investments
Defined Benefit Plan Disclosure [Line Items]
Target Allocation	0.00%
Plan Asset Allocations	0.00%	0.00%

Employee_Benefit_Plans_Fair_Va

Employee Benefit Plans - Fair Values of Pension Plan Assets Recorded at Each Fair Value Hierarchy Level (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	$551	$531	$483
Canada
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	1,050	1,040	961
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	551	531
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	3	2
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	262	240
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	233	240
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	53	49
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	498	482
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	3	2
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	262	240
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 1 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	233	240
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 1 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 2 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 2 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	53	49
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 3 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 3 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | U.S. | Fair Value, Measurements, Recurring | Level 3 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	53	49
Qualified pension plans | Canada | Fair Value, Measurements, Recurring
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	1,050	1,040
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	3	8
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	471	442
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	576	590
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 1
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	816	878
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	3	8
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 1 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	471	442
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 1 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	342	428
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 1 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 2
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	234	162
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 2 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 2 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	234	162
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 2 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 3
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 3 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 3 | Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 3 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Qualified pension plans | Canada | Fair Value, Measurements, Recurring | Level 3 | Other
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	$0	$0

Employee_Benefit_Plans_Changes

Employee Benefit Plans - Changes in Level 3 Assets That are Measured at Fair Value on Recurring Basis (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
U.S.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value, beginning of period	$49	$69
Sales	0	-25
Gain (loss) included in other comprehensive income	4	4
Settlements	0	1
Fair value, end of period	53	49
Canada
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value, beginning of period	0	1
Sales	0	0
Gain (loss) included in other comprehensive income	0	-1
Settlements	0	0
Fair value, end of period	$0	$0

Employee_Benefit_Plans_Expecte

Employee Benefit Plans - Expected Benefit Payments (Detail) (Qualified pension plans, USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
U.S.
Defined Benefit Plan Disclosure [Line Items]
2015	$42
2016	47
2017	50
2018	49
2019	53
2020- 2024	235
Canada
Defined Benefit Plan Disclosure [Line Items]
2015	51
2016	54
2017	57
2018	60
2019	63
2020- 2024	$346

Employee_Benefit_Plans_Other_P

Employee Benefit Plans - Other Post Retirement Benefit Plans Change in Projected Benefit Obligation and Fair Value of Plan Assets (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
U.S.
Change in Benefit Obligation
Projected benefit obligation, beginning balance	$184		$202
Transfers in	0		0
Service cost	1		1		1
Interest cost	8		7		8
Plan participants' contributions	2		3
Actuarial loss (gain)	-7		-13
Medicare subsidy receivable	2		2
Benefits paid	-18		-18
Foreign currency translation effect	0		0
Projected benefit obligation, ending balance	172		184		202
Change in Fair Value of Plan Assets
Plan assets, beginning of period	87		79
Actual return on plan assets	7		10
Benefits paid	-18		-18
Employer contributions	14		13
Plan participants’ contributions	2		3
Plan assets, end of period	92		87		79
Net amount recognized	-80	[1]	-97	[1]
Canada
Change in Benefit Obligation
Projected benefit obligation, beginning balance	133		149
Transfers in	0		1
Service cost	4		5		7
Interest cost	6		6		7
Plan participants' contributions	0		0
Actuarial loss (gain)	7		-13
Medicare subsidy receivable	0		0
Benefits paid	-4		-5
Foreign currency translation effect	-13		-10
Projected benefit obligation, ending balance	133		133		149
Change in Fair Value of Plan Assets
Plan assets, beginning of period	0		0
Actual return on plan assets	0		0
Benefits paid	-4		-5
Employer contributions	4		5
Plan participants’ contributions	0		0
Plan assets, end of period	0		0		0
Net amount recognized	($133)	[1]	($133)	[1]
[1]	Recognized primarily in Deferred Credits and Other Liabilities—Regulatory and Other in the Consolidated Balance Sheets.

Employee_Benefit_Plans_Other_P1

Employee Benefit Plans - Other Post Retirement Benefit Plans Amounts Recognized in Accumulated Other Comprehensive Income (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
U.S.
Defined Benefit Plan Disclosure [Line Items]
Prior service cost	$0	$0
Net actuarial loss	-4	6
Total amount recognized in AOCI	-4	6
Canada
Defined Benefit Plan Disclosure [Line Items]
Prior service cost	-4	-5
Net actuarial loss	12	6
Total amount recognized in AOCI	$8	$1

Employee_Benefit_Plans_Other_P2

Employee Benefit Plans - Other Post Retirement Benefit Plans Components of Net Periodic Benefit Cost (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
U.S.
Other Post-Retirement Benefit Plans-Components of Net Periodic Benefit Cost
Service cost benefit earned	$1	$1	$1
Interest cost on accumulated post-retirement benefit obligation	8	7	8
Expected return on plan assets	-5	-4	-5
Amortization of prior service credit	0	0	0
Amortization of loss	1	2	2
Net periodic other post-retirement benefit cost	5	6	6
Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	-9	-18	6
Amortization of actuarial loss	-1	-2	-2
Amortization of prior service credit	0	0	0
Total recognized in other comprehensive income	-10	-20	4
Total recognized in net periodic benefit cost and other comprehensive income	-5	-14	10
Canada
Other Post-Retirement Benefit Plans-Components of Net Periodic Benefit Cost
Service cost benefit earned	4	5	7
Interest cost on accumulated post-retirement benefit obligation	6	6	7
Expected return on plan assets	0	0	0
Amortization of prior service credit	-1	-1	-1
Amortization of loss	0	0	2
Net periodic other post-retirement benefit cost	9	10	15
Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income
Current year actuarial loss (gain)	6	-13	-26
Amortization of actuarial loss	0	0	-2
Amortization of prior service credit	1	1	1
Total recognized in other comprehensive income	7	-12	-27
Total recognized in net periodic benefit cost and other comprehensive income	$16	($2)	($12)

Employee_Benefit_Plans_Other_P3

Employee Benefit Plans - Other Post Retirement Benefits Plans Assumptions Used for Benefits Accounting (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
U.S.
Benefit Obligations
Discount rate	4.08%	4.46%	3.70%
Salary increase	4.00%	4.61%	4.61%
Net Periodic Benefit Cost
Discount rate	4.46%	3.70%	4.31%
Salary increase	4.61%	4.61%	4.61%
Expected return on plan assets	6.98%	6.51%	6.54%
Canada
Benefit Obligations
Discount rate	4.00%	4.83%	4.20%
Salary increase	3.25%	3.25%	3.25%
Net Periodic Benefit Cost
Discount rate	4.83%	4.20%	4.33%
Salary increase	3.25%	3.25%	3.25%

Employee_Benefit_Plans_Assumed

Employee Benefit Plans - Assumed Health Care Cost Trend Rates (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
U.S.
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	7.00%	7.00%
Rate to which the cost trend is assumed to decline	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2019	2019
Canada
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.00%	6.50%
Rate to which the cost trend is assumed to decline	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2017	2017

Employee_Benefit_Plans_Sensiti

Employee Benefit Plans - Sensitivity to Changes in Assumed Health Care Cost Trend Rates (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
U.S.
Defined Benefit Plan Disclosure [Line Items]
Effect of 1% point increase on total service and interest costs	$0
Effect of 1% point increase on post-retirement benefit obligations	7
Effect of 1% point decrease on total service and interest costs	0
Effect of 1% point decrease on post-retirement benefit obligations	-6
Canada
Defined Benefit Plan Disclosure [Line Items]
Effect of 1% point increase on total service and interest costs	1
Effect of 1% point increase on post-retirement benefit obligations	9
Effect of 1% point decrease on total service and interest costs	-1
Effect of 1% point decrease on post-retirement benefit obligations	($7)

Employee_Benefit_Plans_Other_P4

Employee Benefit Plans - Other Post Retirement Plan Assets (Detail) (U.S., USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	$92	$87	$79
Plan asset allocations	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	48.00%	49.00%
Fixed Income Securities
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	47.00%	46.00%
Other Assets
Defined Benefit Plan Disclosure [Line Items]
Plan asset allocations	5.00%	5.00%

Employee_Benefit_Plans_Fair_Va1

Employee Benefit Plans - Fair Values of Other Post-Retirement Plan Assets Recorded at Each Hierarchy Level (Detail) (U.S., USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	$92	$87	$79
Fair Value, Measurements, Recurring | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	46	43
Fair Value, Measurements, Recurring | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	46	44
Fair Value, Measurements, Recurring | Fixed Income Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	21	20
Fair Value, Measurements, Recurring | Fixed Income Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	22	20
Fair Value, Measurements, Recurring | Equity Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	25	23
Fair Value, Measurements, Recurring | Equity Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	20	20
Fair Value, Measurements, Recurring | Other Security Investments | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Fair Value, Measurements, Recurring | Other Security Investments | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	4	4
Level 1 | Fair Value, Measurements, Recurring | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 1 | Fair Value, Measurements, Recurring | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	42	40
Level 1 | Fair Value, Measurements, Recurring | Fixed Income Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 1 | Fair Value, Measurements, Recurring | Fixed Income Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	22	20
Level 1 | Fair Value, Measurements, Recurring | Equity Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 1 | Fair Value, Measurements, Recurring | Equity Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	20	20
Level 1 | Fair Value, Measurements, Recurring | Other Security Investments | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 1 | Fair Value, Measurements, Recurring | Other Security Investments | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 2 | Fair Value, Measurements, Recurring | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	46	43
Level 2 | Fair Value, Measurements, Recurring | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 2 | Fair Value, Measurements, Recurring | Fixed Income Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	21	20
Level 2 | Fair Value, Measurements, Recurring | Fixed Income Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 2 | Fair Value, Measurements, Recurring | Equity Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	25	23
Level 2 | Fair Value, Measurements, Recurring | Equity Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 2 | Fair Value, Measurements, Recurring | Other Security Investments | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 2 | Fair Value, Measurements, Recurring | Other Security Investments | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	4	4
Level 3 | Fair Value, Measurements, Recurring | Fixed Income Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Fixed Income Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Equity Securities | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Equity Securities | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Other Security Investments | Veba Trust
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	0	0
Level 3 | Fair Value, Measurements, Recurring | Other Security Investments | Master Trust Fund
Defined Benefit Plan Disclosure [Line Items]
Fair values of plan assets	$4	$4

Employee_Benefit_Plans_Changes1

Employee Benefit Plans - Changes in Level 3 Assets That are Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs (Detail) (U.S., USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
U.S.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value, beginning of period	$4	$5
Sales	0	-2
Unrealized gain included in other comprehensive income	0	1
Fair value, end of period	$4	$4

Employee_Benefit_Plans_Benefit

Employee Benefit Plans - Benefit Payments and Subsidies Expected to be Paid (or Received) (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
U.S.
Benefit payments
2015	$16
2016	15
2017	15
2018	14
2019	14
2020- 2024	60
Medicare Part D subsidy receipts
2015	-2
2016	-2
2017	-1
2018	-1
2019	-1
2020 - 2024	-6
Canada
Benefit payments
2015	5
2016	5
2017	5
2018	6
2019	6
2020- 2024	$33

Condensed_Consolidating_Statem

Condensed Consolidating Statement of Operations (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Total operating revenues	$1,600	$1,207	$1,253	$1,843	$1,565	$1,144	$1,220	$1,589	$5,903	[1]	$5,518	[1]	$5,075	[1]
Total operating expenses									3,979		3,852		3,500
Operating Income	565	382	338	639	473	333	354	506	1,924		1,666		1,575
Equity in earnings of unconsolidated affiliates									361		445		382
Equity in earnings of consolidated subsidiaries									0		0		0
Other income and expenses, net									59		124		83
Interest expense									679		657		625
Earnings From Continuing Operations Before Income Taxes									1,665	[1]	1,578	[1]	1,415	[1]
Income tax expense (benefit)									382		419		370
Income From Continuing Operations									1,283		1,159		1,045
Income (loss) from discontinued operations, net of tax									0		0		2
Net income	374	254	188	467	271	292	226	370	1,283		1,159		1,047
Net income — noncontrolling interests									201		121		107
Net income — controlling interests	316	201	146	419	236	263	199	340	1,082		1,038		940
Spectra Energy Corp
Condensed Financial Statements, Captions [Line Items]
Total operating revenues									0		0		0
Total operating expenses									6		8		5
Operating Income									-6		-8		-5
Equity in earnings of unconsolidated affiliates									0		0		0
Equity in earnings of consolidated subsidiaries									1,054		1,015		917
Other income and expenses, net									-2		1		-2
Interest expense									0		0		0
Earnings From Continuing Operations Before Income Taxes									1,046		1,008		910
Income tax expense (benefit)									-36		-30		-31
Income From Continuing Operations													941
Income (loss) from discontinued operations, net of tax													-1
Net income									1,082		1,038		940
Net income — noncontrolling interests									0		0		0
Net income — controlling interests									1,082		1,038		940
Spectra Energy Capital
Condensed Financial Statements, Captions [Line Items]
Total operating revenues									0		0		0
Total operating expenses									1		3		5
Operating Income									-1		-3		-5
Equity in earnings of unconsolidated affiliates									0		0	[2]	0	[3]
Equity in earnings of consolidated subsidiaries									1,651		1,649	[2]	1,377	[3]
Other income and expenses, net									9		15		3
Interest expense									253		216		190
Earnings From Continuing Operations Before Income Taxes									1,406		1,445		1,185
Income tax expense (benefit)									352		430		268
Income From Continuing Operations													917
Income (loss) from discontinued operations, net of tax													0
Net income									1,054		1,015	[2]	917	[3]
Net income — noncontrolling interests									0		0		0
Net income — controlling interests									1,054		1,015		917
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Total operating revenues									5,906		5,521		5,077
Total operating expenses									3,975		3,844		3,492
Operating Income									1,931		1,677		1,585
Equity in earnings of unconsolidated affiliates									361		445	[2]	382	[3]
Equity in earnings of consolidated subsidiaries									0		0	[2]	0	[3]
Other income and expenses, net									52		108		82
Interest expense									426		441		435
Earnings From Continuing Operations Before Income Taxes									1,918		1,789		1,614
Income tax expense (benefit)									66		19		133
Income From Continuing Operations													1,481
Income (loss) from discontinued operations, net of tax													3
Net income									1,852		1,770	[2]	1,484	[3]
Net income — noncontrolling interests									201		121		107
Net income — controlling interests									1,651		1,649		1,377
Eliminations
Condensed Financial Statements, Captions [Line Items]
Total operating revenues									-3		-3		-2
Total operating expenses									-3		-3		-2
Operating Income									0		0		0
Equity in earnings of unconsolidated affiliates									0		0		0
Equity in earnings of consolidated subsidiaries									-2,705		-2,664		-2,294
Other income and expenses, net									0		0		0
Interest expense									0		0		0
Earnings From Continuing Operations Before Income Taxes									-2,705		-2,664		-2,294
Income tax expense (benefit)									0		0		0
Income From Continuing Operations													-2,294
Income (loss) from discontinued operations, net of tax													0
Net income									-2,705		-2,664		-2,294
Net income — noncontrolling interests									0		0		0
Net income — controlling interests									($2,705)		($2,664)		($2,294)
[1]	Excludes amounts associated with entities included in discontinued operations.
[2]	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
[3]	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Condensed_Consolidating_Statem1

Condensed Consolidating Statements of Comprehensive Income (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Net income	$374	$254	$188	$467	$271	$292	$226	$370	$1,283	$1,159		$1,047
Other comprehensive income (loss)									-586	-275		239
Total Comprehensive Income, net of tax									697	884		1,286
Less: comprehensive income — noncontrolling interests									194	114		110
Comprehensive Income — Controlling Interests									503	770		1,176
Spectra Energy Corp
Condensed Financial Statements, Captions [Line Items]
Net income									1,082	1,038		940
Other comprehensive income (loss)									9	69		-12
Total Comprehensive Income, net of tax									1,091	1,107		928
Less: comprehensive income — noncontrolling interests									0	0		0
Comprehensive Income — Controlling Interests									1,091	1,107		928
Spectra Energy Capital
Condensed Financial Statements, Captions [Line Items]
Net income									1,054	1,015	[1]	917	[2]
Other comprehensive income (loss)									1	2		3
Total Comprehensive Income, net of tax									1,055	1,017		920
Less: comprehensive income — noncontrolling interests									0	0		0
Comprehensive Income — Controlling Interests									1,055	1,017		920
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income									1,852	1,770	[1]	1,484	[2]
Other comprehensive income (loss)									-596	-346		248
Total Comprehensive Income, net of tax									1,256	1,424		1,732
Less: comprehensive income — noncontrolling interests									194	114		110
Comprehensive Income — Controlling Interests									1,062	1,310		1,622
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income									-2,705	-2,664		-2,294
Other comprehensive income (loss)									0	0		0
Total Comprehensive Income, net of tax									-2,705	-2,664		-2,294
Less: comprehensive income — noncontrolling interests									0	0		0
Comprehensive Income — Controlling Interests									($2,705)	($2,664)		($2,294)
[1]	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
[2]	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Condensed_Consolidating_Balanc

Condensed Consolidating Balance Sheet (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	$215		$201		$94	$174
Receivables - consolidated subsidiaries	0		0
Receivables - other	1,336		1,336
Other current assets	781		544
Total current assets	2,332		2,081
Investments in and loans to unconsolidated affiliates	2,966		3,043
Investments in consolidated subsidiaries	0		0
Advances receivable - consolidated subsidiaries	0		0
Notes receivable - consolidated subsidiaries	0		0
Goodwill	4,714		4,810		4,513
Other assets	327		385
Property, plant and equipment, net	22,307		21,829
Regulatory assets and deferred debits	1,394		1,385
Total Assets	34,040		33,533		30,587
Accounts payable - other	458		440
Accounts payable - consolidated subsidiaries	0		0
Commercial paper	1,583	[1],[2]	1,032	[1],[2]
Short-term borrowings - consolidated subsidiaries	0		0
Taxes accrued	91		72
Current maturities of long-term debt	327		1,197
Other current liabilities	1,350		1,298
Total current liabilities	3,809		4,039
Long-term debt	12,769		12,488
Advances payable - consolidated subsidiaries	0		0
Notes payable — consolidated subsidiaries	0
Deferred credits and other liabilities	6,806		6,425
Preferred stock of subsidiaries	258		258
Equity
Total controlling interests	8,160		8,494
Noncontrolling interests	2,238		1,829
Total equity	10,398		10,323		9,843	8,896
Total Liabilities and Equity	34,040		33,533
Spectra Energy Corp
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0		0		0
Receivables - consolidated subsidiaries	18		176
Receivables - other	2		1
Other current assets	71		40
Total current assets	91		217
Investments in and loans to unconsolidated affiliates	0		0
Investments in consolidated subsidiaries	14,531		13,244
Advances receivable - consolidated subsidiaries	0		0
Notes receivable - consolidated subsidiaries	0		0
Goodwill	0		0
Other assets	38		39
Property, plant and equipment, net	0		0
Regulatory assets and deferred debits	4		3
Total Assets	14,664		13,503
Accounts payable - other	3		4
Accounts payable - consolidated subsidiaries	0		89
Commercial paper	0		0
Short-term borrowings - consolidated subsidiaries	0		0
Taxes accrued	5		4
Current maturities of long-term debt	0		0
Other current liabilities	96		81
Total current liabilities	104		178
Long-term debt	0		0
Advances payable - consolidated subsidiaries	5,581		4,715
Notes payable — consolidated subsidiaries	0
Deferred credits and other liabilities	819		116
Preferred stock of subsidiaries	0		0
Equity
Total controlling interests	8,160		8,494
Noncontrolling interests	0		0
Total equity	8,160		8,494
Total Liabilities and Equity	14,664		13,503
Spectra Energy Capital, LLC
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	1		12		3	2	[3]
Receivables - consolidated subsidiaries	0		394
Receivables - other	0		0
Other current assets	2		15
Total current assets	3		421
Investments in and loans to unconsolidated affiliates	0		0
Investments in consolidated subsidiaries	20,562		19,403
Advances receivable - consolidated subsidiaries	4,683		4,038
Notes receivable - consolidated subsidiaries	0		0
Goodwill	0		0
Other assets	22		30
Property, plant and equipment, net	0		0
Regulatory assets and deferred debits	15		17
Total Assets	25,285		23,909
Accounts payable - other	0		0
Accounts payable - consolidated subsidiaries	17		0
Commercial paper	398		344
Short-term borrowings - consolidated subsidiaries	398		415
Taxes accrued	0		0
Current maturities of long-term debt	0		557
Other current liabilities	54		75
Total current liabilities	867		1,391
Long-term debt	2,900		2,605
Advances payable - consolidated subsidiaries	0		0
Notes payable — consolidated subsidiaries	2,800		2,800
Deferred credits and other liabilities	4,187		3,869
Preferred stock of subsidiaries	0		0
Equity
Total controlling interests	14,531		13,244
Noncontrolling interests	0		0
Total equity	14,531		13,244
Total Liabilities and Equity	25,285		23,909
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	214		189		91	172	[3]
Receivables - consolidated subsidiaries	11		0
Receivables - other	1,334		1,335
Other current assets	708		489
Total current assets	2,267		2,013
Investments in and loans to unconsolidated affiliates	2,966		3,043
Investments in consolidated subsidiaries	0		0
Advances receivable - consolidated subsidiaries	898		677
Notes receivable - consolidated subsidiaries	3,198		3,215
Goodwill	4,714		4,810
Other assets	267		316
Property, plant and equipment, net	22,307		21,829
Regulatory assets and deferred debits	1,375		1,365
Total Assets	37,992		37,268
Accounts payable - other	455		436
Accounts payable - consolidated subsidiaries	12		481
Commercial paper	1,185		688
Short-term borrowings - consolidated subsidiaries	0		0
Taxes accrued	86		68
Current maturities of long-term debt	327		640
Other current liabilities	1,200		1,142
Total current liabilities	3,265		3,455
Long-term debt	9,869		9,883
Advances payable - consolidated subsidiaries	0		0
Notes payable — consolidated subsidiaries	0
Deferred credits and other liabilities	1,800		2,440
Preferred stock of subsidiaries	258		258
Equity
Total controlling interests	20,562		19,403
Noncontrolling interests	2,238		1,829
Total equity	22,800		21,232
Total Liabilities and Equity	37,992		37,268
Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0		0		0
Receivables - consolidated subsidiaries	-29		-570
Receivables - other	0		0
Other current assets	0		0
Total current assets	-29		-570
Investments in and loans to unconsolidated affiliates	0		0
Investments in consolidated subsidiaries	-35,093		-32,647
Advances receivable - consolidated subsidiaries	-5,581		-4,715
Notes receivable - consolidated subsidiaries	-3,198		-3,215
Goodwill	0		0
Other assets	0		0
Property, plant and equipment, net	0		0
Regulatory assets and deferred debits	0		0
Total Assets	-43,901		-41,147
Accounts payable - other	0		0
Accounts payable - consolidated subsidiaries	-29		-570
Commercial paper	0		0
Short-term borrowings - consolidated subsidiaries	-398		-415
Taxes accrued	0		0
Current maturities of long-term debt	0		0
Other current liabilities	0		0
Total current liabilities	-427		-985
Long-term debt	0		0
Advances payable - consolidated subsidiaries	-5,581		-4,715
Notes payable — consolidated subsidiaries	-2,800		-2,800
Deferred credits and other liabilities	0		0
Preferred stock of subsidiaries	0		0
Equity
Total controlling interests	-35,093		-32,647
Noncontrolling interests	0		0
Total equity	-35,093		-32,647
Total Liabilities and Equity	($43,901)		($41,147)
[1]	The weighted-average days to maturity was 14 days as of December 31, 2014 and 9 days as of December 31, 2013.
[2]	Weighted-average rate on outstanding commercial paper was 0.6% at both December 31, 2014 and 2013.
[3]	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Condensed_Consolidating_Statem2

Condensed Consolidating Statement of Cash Flows (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$1,283	$1,159		$1,047
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	809	787		760
Equity in earnings of unconsolidated affiliates	-361	-445		-382
Equity in earnings of consolidated subsidiaries	0	0		0
Distributions received from unconsolidated affiliates	380	324		307
Other	110	205		206
Net cash provided by operating activities	2,221	2,030		1,938
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	-2,028	-1,947		-2,025
Investments in and loans to unconsolidated affiliates	-259	-312		-520
Acquisitions, net of cash acquired	0	-1,254		-30
Purchases of held-to-maturity securities	-790	-985		-2,671
Proceeds from sales and maturities of held-to-maturity securities	815	1,023		2,578
Purchases of available-for-sale securities	-13	-5,878		-644
Proceeds from sales and maturities of available-for-sale securities	7	6,024		514
Distributions received from unconsolidated affiliates	266	87		17
Advances from (to) affiliates	0	0		0
Loan to unconsolidated affiliate	0	-71		0
Repayment of loan to unconsolidated affiliate	0	71		0
Other changes in restricted funds	-1	2		93
Other	0	4		14
Net cash used in investing activities	-2,003	-3,236		-2,674
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,028	4,372		1,301
Payments for the redemption of long-term debt	-1,184	-2,139		-525
Net increase (decrease) in commercial paper	574	-206		199
Net decrease in revolving credit facilities borrowings		0		0
Distributions to noncontrolling interests	-175	-144		-120
Contributions from noncontrolling interests	145	23		0
Proceeds from the issuance of Spectra Energy Partners common units	327	214		145
Proceeds from the issuance of Spectra Energy common stock	0	0		382
Dividends paid on common stock	-925	-821		-753
Distributions and advances from (to) affiliates	0	0		0
Other	11	17		25
Net cash provided by (used in) financing activities	-199	1,316		654
Effect of exchange rate changes on cash	-5	-3		2
Net increase (decrease) in cash and cash equivalents	14	107		-80
Cash and cash equivalents at beginning of period	201	94		174
Cash and cash equivalents at end of period	215	201		94
Spectra Energy Corp
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	1,082	1,038		940
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	0	0		0
Equity in earnings of unconsolidated affiliates	0	0		0
Equity in earnings of consolidated subsidiaries	-1,054	-1,015		-917
Distributions received from unconsolidated affiliates	0	0		0
Other	14	-2		-86
Net cash provided by operating activities	42	21		-63
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	0	0		0
Investments in and loans to unconsolidated affiliates	0	0		0
Acquisitions, net of cash acquired		0		0
Purchases of held-to-maturity securities	0	0		0
Proceeds from sales and maturities of held-to-maturity securities	0	0		0
Purchases of available-for-sale securities	0	0		0
Proceeds from sales and maturities of available-for-sale securities	0	0		0
Distributions received from unconsolidated affiliates	0	0		0
Advances from (to) affiliates	92	-75		-163
Loan to unconsolidated affiliate		0
Repayment of loan to unconsolidated affiliate		0
Other changes in restricted funds	0	0		0
Other		0		0
Net cash used in investing activities	92	-75		-163
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	0	0		0
Payments for the redemption of long-term debt	0	0		0
Net increase (decrease) in commercial paper	0	0		0
Net decrease in revolving credit facilities borrowings		0		0
Distributions to noncontrolling interests	0	0		0
Contributions from noncontrolling interests	0	0
Proceeds from the issuance of Spectra Energy Partners common units	0	0		0
Proceeds from the issuance of Spectra Energy common stock				382
Dividends paid on common stock	-925	-821		-753
Distributions and advances from (to) affiliates	777	847		564
Other	14	28		33
Net cash provided by (used in) financing activities	-134	54		226
Effect of exchange rate changes on cash	0	0		0
Net increase (decrease) in cash and cash equivalents	0	0		0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	0	0		0
Spectra Energy Capital, LLC
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	1,054	1,015	[1]	917	[2]
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	0	0	[1]	0	[2]
Equity in earnings of unconsolidated affiliates	0	0	[1]	0	[2]
Equity in earnings of consolidated subsidiaries	-1,651	-1,649	[1]	-1,377	[2]
Distributions received from unconsolidated affiliates	0	0	[1]	0	[2]
Other	304	478	[1]	246	[2]
Net cash provided by operating activities	-293	-156	[1]	-214	[2]
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	0	0	[1]	0	[2]
Investments in and loans to unconsolidated affiliates	0	0	[1]	0	[2]
Acquisitions, net of cash acquired		0	[1]	0	[2]
Purchases of held-to-maturity securities	0	0	[1]	0	[2]
Proceeds from sales and maturities of held-to-maturity securities	0	0	[1]	0	[2]
Purchases of available-for-sale securities	0	0	[1]	0	[2]
Proceeds from sales and maturities of available-for-sale securities	0	0	[1]	0	[2]
Distributions received from unconsolidated affiliates	0	0	[1]	0	[2]
Advances from (to) affiliates	495	-1,856	[1]	-335	[2]
Loan to unconsolidated affiliate		0	[1]
Repayment of loan to unconsolidated affiliate		71	[1]
Other changes in restricted funds	0	0	[1]	0	[2]
Other		0		0	[2]
Net cash used in investing activities	495	-1,785	[1]	-335	[2]
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	300	1,848		0	[2]
Payments for the redemption of long-term debt	-557	-1,944		0	[2]
Net increase (decrease) in commercial paper	54	-170		-238	[2]
Net decrease in revolving credit facilities borrowings		-497	[1]	322	[2]
Distributions to noncontrolling interests	0	0	[1]	0	[2]
Contributions from noncontrolling interests	0	0
Proceeds from the issuance of Spectra Energy Partners common units	0	0	[1]	0	[2]
Proceeds from the issuance of Spectra Energy common stock				0	[2]
Dividends paid on common stock	0	0	[1]	0	[2]
Distributions and advances from (to) affiliates	-10	2,718	[1]	466	[2]
Other	0	-5	[1]	0	[2]
Net cash provided by (used in) financing activities	-213	1,950	[1]	550	[2]
Effect of exchange rate changes on cash	0	0		0	[2]
Net increase (decrease) in cash and cash equivalents	-11	9		1	[2]
Cash and cash equivalents at beginning of period	12	3		2	[2]
Cash and cash equivalents at end of period	1	12		3
Non-Guarantor Subsidiaries
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	1,852	1,770	[1]	1,484	[2]
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	809	787	[1]	760	[2]
Equity in earnings of unconsolidated affiliates	-361	-445	[1]	-382	[2]
Equity in earnings of consolidated subsidiaries	0	0	[1]	0	[2]
Distributions received from unconsolidated affiliates	380	324	[1]	307	[2]
Other	-208	-271	[1]	46	[2]
Net cash provided by operating activities	2,472	2,165	[1]	2,215	[2]
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	-2,028	-1,947	[1]	-2,025	[2]
Investments in and loans to unconsolidated affiliates	-259	-312	[1]	-520	[2]
Acquisitions, net of cash acquired		-1,254	[1]	-30	[2]
Purchases of held-to-maturity securities	-790	-985	[1]	-2,671	[2]
Proceeds from sales and maturities of held-to-maturity securities	815	1,023	[1]	2,578	[2]
Purchases of available-for-sale securities	-13	-5,878	[1]	-644	[2]
Proceeds from sales and maturities of available-for-sale securities	7	6,024	[1]	514	[2]
Distributions received from unconsolidated affiliates	266	87	[1]	17	[2]
Advances from (to) affiliates	0	0	[1]	888	[2]
Loan to unconsolidated affiliate		-71	[1]
Repayment of loan to unconsolidated affiliate		0	[1]
Other changes in restricted funds	-1	2	[1]	93	[2]
Other		4		14	[2]
Net cash used in investing activities	-2,003	-3,307	[1]	-1,786	[2]
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	728	2,524		1,301	[2]
Payments for the redemption of long-term debt	-627	-195		-525	[2]
Net increase (decrease) in commercial paper	520	-36		437	[2]
Net decrease in revolving credit facilities borrowings		0	[1]	0	[2]
Distributions to noncontrolling interests	-175	-144	[1]	-120	[2]
Contributions from noncontrolling interests	145	23
Proceeds from the issuance of Spectra Energy Partners common units	327	214	[1]	145	[2]
Proceeds from the issuance of Spectra Energy common stock				0	[2]
Dividends paid on common stock	0	0	[1]	0	[2]
Distributions and advances from (to) affiliates	-1,354	-1,137	[1]	-1,742	[2]
Other	-3	-6	[1]	-8	[2]
Net cash provided by (used in) financing activities	-439	1,243	[1]	-512	[2]
Effect of exchange rate changes on cash	-5	-3		2	[2]
Net increase (decrease) in cash and cash equivalents	25	98		-81	[2]
Cash and cash equivalents at beginning of period	189	91		172	[2]
Cash and cash equivalents at end of period	214	189		91
Eliminations
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	-2,705	-2,664		-2,294
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	0	0		0
Equity in earnings of unconsolidated affiliates	0	0		0
Equity in earnings of consolidated subsidiaries	2,705	2,664		2,294
Distributions received from unconsolidated affiliates	0	0		0
Other	0	0		0
Net cash provided by operating activities	0	0		0
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	0	0		0
Investments in and loans to unconsolidated affiliates	0	0		0
Acquisitions, net of cash acquired		0		0
Purchases of held-to-maturity securities	0	0		0
Proceeds from sales and maturities of held-to-maturity securities	0	0		0
Purchases of available-for-sale securities	0	0		0
Proceeds from sales and maturities of available-for-sale securities	0	0		0
Distributions received from unconsolidated affiliates	0	0		0
Advances from (to) affiliates	-587	1,931		-390
Loan to unconsolidated affiliate		0
Repayment of loan to unconsolidated affiliate		0
Other changes in restricted funds	0	0		0
Other		0		0
Net cash used in investing activities	-587	1,931		-390
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	0	0		0
Payments for the redemption of long-term debt	0	0		0
Net increase (decrease) in commercial paper	0	0		0
Net decrease in revolving credit facilities borrowings		497		-322
Distributions to noncontrolling interests	0	0		0
Contributions from noncontrolling interests	0	0
Proceeds from the issuance of Spectra Energy Partners common units	0	0		0
Proceeds from the issuance of Spectra Energy common stock				0
Dividends paid on common stock	0	0		0
Distributions and advances from (to) affiliates	587	-2,428		712
Other	0	0		0
Net cash provided by (used in) financing activities	587	-1,931		390
Effect of exchange rate changes on cash	0	0		0
Net increase (decrease) in cash and cash equivalents	0	0		0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	$0	$0		$0
[1]	Excludes the effects of $3,869 million of non-cash equitizations of advances receivable owed to Spectra Capital.
[2]	Excludes the effects of $1,207 million of non-cash equitizations of advances receivable owed to Spectra Capital.

Condensed_Consolidating_Statem3

Condensed Consolidating Statement of Cash Flows (Notes) (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Condensed Financial Statements, Captions [Line Items]
Non-cash equitization of advances receivables owed to Spectra Capital	$3,869	$1,207

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Detail) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$1,600		$1,207		$1,253		$1,843		$1,565		$1,144		$1,220		$1,589		$5,903	[1]	$5,518	[1]	$5,075	[1]
Operating Income	565		382		338		639		473		333		354		506		1,924		1,666		1,575
Net income	374		254		188		467		271		292		226		370		1,283		1,159		1,047
Net income — controlling interests	$316		$201		$146		$419		$236		$263		$199		$340		$1,082		$1,038		$940
Earnings per share
Basic (in usd per share)	$0.47	[2]	$0.30	[2]	$0.22	[2]	$0.63	[2]	$0.35	[2]	$0.39	[2]	$0.30	[2]	$0.51	[2]	$1.61	[2]	$1.55	[2]	$1.44
Diluted (in usd per share)	$0.47	[2]	$0.30	[2]	$0.22	[2]	$0.62	[2]	$0.35	[2]	$0.39	[2]	$0.30	[2]	$0.51	[2]	$1.61	[2]	$1.55	[2]	$1.43
[1]	Excludes amounts associated with entities included in discontinued operations.
[2]	Quarterly earnings-per-share amounts are stand-alone calculations and may not be additive to full-year amounts due to rounding.

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) - Additional Information (Detail) (Unusual or Infrequent Item, USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2013
Operating Income
Effect of Fourth Quarter Events [Line Items]
Effect of third quarter events amount	$23
Net Income
Effect of Fourth Quarter Events [Line Items]
Effect of third quarter events amount	22
Net Income-Controlling Interests
Effect of Fourth Quarter Events [Line Items]
Effect of third quarter events amount	20
Operating Income, Net Income and Net Income-Controlling Interests
Effect of Fourth Quarter Events [Line Items]
Effect of fourth quarter events, amount		11
Net Income and Net Income-Controlling Interests
Effect of Fourth Quarter Events [Line Items]
Effect of fourth quarter events, amount		$31

Valuation_and_Qualifying_Accou

Valuation and Qualifying Accounts and Reserves (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$174		$194		$185
Additions Charged to Expense	35		28		74
Additions Charged to Other Accounts	0		0		1
Deductions	85	[1]	48	[1]	66	[1]
Balance at End of Period	124		174		194
Allowance for Doubtful Accounts
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	10		13		14
Additions Charged to Expense	6		7		10
Additions Charged to Other Accounts	0		0		1
Deductions	5	[1]	10	[1]	12	[1]
Balance at End of Period	11		10		13
Other
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	164	[2]	181	[2]	171	[2]
Additions Charged to Expense	29	[2]	21	[2]	64	[2]
Additions Charged to Other Accounts	0	[2]	0	[2]	0	[2]
Deductions	80	[1],[2]	38	[1],[2]	54	[1],[2]
Balance at End of Period	$113	[2]	$164	[2]	$181	[2]
[1]	Principally cash payments and reserve reversals.
[2]	Principally income tax, insurance-related, litigation and other reserves, included primarily in Deferred Credits and Other Liabilities—Regulatory and Other on the Consolidated Balance Sheets.