Enbridge Energy Partners 10-Q 3 Aug 18 2018 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 31, 2018
Document And Entity Information [Abstract]
Entity Registrant Name	ENBRIDGE ENERGY PARTNERS LP
Entity Central Index Key	880,285
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Trading Symbol	EEP
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		326,517,110
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating revenues:
Revenues	$ 537	$ 596	$ 1,129	$ 1,201
Operating expenses:
Environmental costs, net of recoveries	(23)	4	(22)	14
Power	75	66	152	140
Depreciation and amortization	109	108	219	217
Impairment of long-lived asset (Note 6)	1	0	36	0
Gain on sale of assets (Note 6)	0	(51)	0	(62)
Total operating expenses	297	285	652	621
Operating income	240	311	477	580
Interest expense, net	101	103	205	202
Allowance for equity used during construction	16	11	32	21
Income from equity investment in joint venture (Note 7)	33	6	56	6
Other income (expense)	(1)	5	(1)	5
Income from continuing operations before income taxes	187	230	359	410
Income tax benefit	0	2	0	1
Income from continuing operations	187	232	359	411
Loss from discontinued operations, net of taxes (Note 6)	0	(35)	0	(57)
Net income	187	197	359	354
Noncontrolling interests (Note 9)	(92)	(91)	(190)	(159)
Series 1 preferred unit distributions	0	(6)	0	(29)
Accretion of discount on Series 1 preferred units	0	(7)	0	(8)
Net income - controlling interests	95	93	169	158
Net income allocable to common units and i-units:
Income from continuing operations	83	105	145	172
Loss from discontinued operations (Note 4)	0	(24)	0	(38)
Net income allocable to common units and i-units	$ 83	$ 81	$ 145	$ 134
Net income per common unit and i-unit (basic and diluted):
Income from continuing operations (in dollars per share)	$ 0.19	$ 0.27	$ 0.34	$ 0.46
Loss from discontinued operations (in dollars per share)	0	(0.06)	0	(0.10)
Net income per common unit and i-unit (in dollars per share)	$ 0.19	$ 0.21	$ 0.34	$ 0.36
Weighted average common units and i-units outstanding (basic and diluted) (in shares)	428	400	427	377
Distributions paid per limited partner unit (in dollars per share)	$ 0.350	$ 0.350	$ 0.700	$ 0.933
Third Party [Member]
Operating expenses:
Operating and administrative	$ 67	$ 84	$ 136	$ 162
Affiliated Entity [Member]
Operating expenses:
Operating and administrative	68	74	131	150
Oil And Gas Service [Member] | Third Party [Member]
Operating revenues:
Revenues	500	569	1,059	1,149
Oil And Gas Service [Member] | Affiliated Entity [Member]
Operating revenues:
Revenues	$ 37	$ 27	$ 70	$ 52

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 187	$ 197	$ 359	$ 354
Other comprehensive income, net of tax
Change in cash flow hedges	0	(19)	0	(21)
Reclassification to income on cash flow hedges	8	10	20	21
Other comprehensive income (loss), net of tax	8	(9)	20	0
Comprehensive income	195	188	379	354
Comprehensive income attributable to noncontrolling interests	(92)	(91)	(190)	(159)
Series 1 preferred unit distributions	0	(6)	0	(29)
Accretion of discount on Series 1 preferred units	0	(7)	0	(8)
Comprehensive income attributable to common units and i-units	$ 103	$ 84	$ 189	$ 158

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Operating activities:
Income from continuing operations	$ 359	$ 411
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	219	217
Changes in unrealized (gain) loss on derivative instruments, net	7	(1)
Environmental costs, net of recoveries	(22)	14
Distributions from equity investment in joint venture	56	0
Income from equity investment in joint venture (Note 7)	(56)	(6)
Gain on sale of assets (Note 6)	0	(62)
Allowance for equity used during construction	(32)	(21)
Amortization of debt issuance and hedging costs	17	19
Impairment of long-lived asset (Note 6)	36	0
Other	1	(2)
Changes in operating assets and liabilities	31	(354)
Net cash provided by operating activities	616	215
Net cash used in discontinued operations	0	(171)
Investing activities:
Capital expenditures	(333)	(229)
Proceeds from the sale of assets	0	314
Proceeds from the sale of Midcoast assets (Note 6)	0	1,310
Equity investment in joint venture	(4)	(1,557)
Distributions from equity investment in joint venture in excess of cumulative earnings	40	0
Other	0	(3)
Net cash used in investing activities	(297)	(165)
Net cash used in discontinued operations	0	(25)
Financing activities:
Redemption of Series 1 Preferred Units (Note 10)	0	(1,200)
Payment of Series 1 Preferred Unit dividends (Note 10)	0	(357)
Net proceeds from Class A common unit issuances (Note 10)	0	1,225
Distributions to partners	(260)	(346)
Repayments to General Partner and affiliates	(157)	(1,829)
Borrowings from General Partner and affiliates	297	1,500
Net borrowings (repayments) under credit facilities (Note 8)	175	(865)
Net commercial paper borrowings (Note 8)	91	676
Repayment of long-term debt (Note 8)	(400)	0
Acquisition of noncontrolling interest in subsidiary (Note 11)	0	(360)
Sale of noncontrolling interest in subsidiary (Note 11)	0	450
Contributions from noncontrolling interests	165	1,285
Distributions to noncontrolling interests	(254)	(219)
Other	(2)	(1)
Net cash used in financing activities	(345)	(41)
Net cash provided by discontinued operations	0	229
Net increase (decrease) in cash and cash equivalents and restricted cash - continuing operations	(26)	9
Net increase in cash and cash equivalents and restricted cash - discontinued operations	0	33
Cash disposed as part of the Midcoast sale	0	(51)
Cash and cash equivalents and restricted cash at beginning of year - continuing operations	35	115
Cash and cash equivalents and restricted cash at beginning of year - discontinued operations	0	18
Cash and cash equivalents and restricted cash at end of period - continuing operations	9	124
Cash and cash equivalents and restricted cash at end of period - discontinued operations	$ 0	$ 0

CONSOLIDATED STATEMENTS OF FINA

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 9	$ 35
Receivables, trade and other	52	65
Due from General Partner and affiliates	107	101
Accrued receivables	91	105
Other current assets	30	24
Assets, Current, Total	289	330
Property, plant and equipment, net	12,978	12,896
Equity investment in joint venture (Note 7)	1,530	1,565
Other assets, net	38	37
Total assets	14,835	14,828
Current liabilities:
Accounts payable and other	188	173
Due to General Partner and affiliates	51	48
Interest payable	81	85
Environmental liabilities	17	23
Property and other taxes payable	87	106
Current portion of long-term debt	600	500
Liabilities, Current	1,024	935
Long-term debt	6,133	6,366
Loans from General Partner and affiliate	750	610
Other long-term liabilities	158	178
Liabilities, Total	8,065	8,089
Commitments and contingencies (Note 12)
Partners’ capital:
General Partner	224	68
Accumulated other comprehensive loss	(179)	(199)
Total Enbridge Energy Partners, L.P. partners’ capital	1,700	1,770
Noncontrolling interests	5,070	4,969
Total Partners’ capital	6,770	6,739
Total Liabilities and Partners’ capital	14,835	14,828
Class E Units [Member]
Partners’ capital:
Common units	774	774
Class A Common Units [Member]
Partners’ capital:
Common units	614	860
Class B Common Units [Member]
Partners’ capital:
Common units	0	0
i-Units [Member]
Partners’ capital:
Common units	0	0
Class F Units [Member]
Partners’ capital:
Common units	267	267
Total Partners’ capital	$ 267	$ 267

CONSOLIDATED STATEMENTS OF FIN6

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION (Parenthetical) - shares	Jun. 30, 2018	Dec. 31, 2017
Class E Units [Member]
Common units, authorized (in shares)	18,100,000	18,100,000
Common units, issued (in shares)	18,100,000	18,100,000
Class A Common Units [Member]
Common units, outstanding (in shares)	326,500,000	326,500,000
Class B Common Units [Member]
Common units, authorized (in shares)	7,800,000	7,800,000
Common units, issued (in shares)	7,800,000	7,800,000
i-Units [Member]
Common units, authorized (in shares)	95,500,000	89,800,000
Common units, issued (in shares)	95,500,000	89,800,000
Class F Units [Member]
Common units, authorized (in shares)	1,000	1,000
Common units, issued (in shares)	1,000	1,000

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - USD ($) $ in Millions	Total	Noncontrolling Interests [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	General Partner [Member]	Class F Units [Member]	Series 1 Preferred units [Member]	Class D Unit [Member]	Class E Unit [Member]	Class A Common Units [Member]	Class B Common Unit [Member]	I Units [Member]	Incentive Distribution Unit [Member]
Beginning balance at Dec. 31, 2016		$ 3,846	$ (339)	$ (667)	$ 0	$ 1,192	$ 2,518	$ 778	$ 0			$ 495
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 158			(9)	7	29		13	150	$ 6	$ (9)
Redemption of preferred units (Note 10)						(1,200)
Waiver of Class D units and incentive distribution units (Note 10)				2,969			(2,479)					(490)
Distribution payable		(219)		(7)	(3)	(29)	(39)	(17)	(267)	(7)		(5)
Issuance of Class F units (Note 10)				(263)	263				1,200
Contributions				25
Sale of Midcoast assets (Note 6)				(2,127)
Accretion of discount on preferred units	8					8
Sale of noncontrolling interest in subsidiary (Note 11)		411		1					29	1	9
Other									0
Changes in fair value of derivative financial instruments recognized in other comprehensive income			(21)
Changes in fair value of derivative financial instruments reclassified to income			21
Capital contributions		1,305
Acquisition of noncontrolling interest in subsidiary (Note 11)		(360)
Sale of Midcoast assets (Note 6)		(297)
Comprehensive income attributable to noncontrolling interests	(159)	159
Ending balance at Jun. 30, 2017	6,581	4,845	(339)	(78)	267	0	0	774	1,112	0	0	0
Beginning balance at Dec. 31, 2017	6,739	4,969	(199)	68	267	0	0	774	860			0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	169			161	8	0		13	(19)	6	0
Redemption of preferred units (Note 10)						0
Waiver of Class D units and incentive distribution units (Note 10)				0			0					0
Distribution payable		(254)		(5)	(8)	0	0	(13)	(229)	(6)		0
Issuance of Class F units (Note 10)				0	0				0
Contributions				0
Sale of Midcoast assets (Note 6)				0
Accretion of discount on preferred units	0					0
Sale of noncontrolling interest in subsidiary (Note 11)		0		0					0	0	0
Other									2
Changes in fair value of derivative financial instruments recognized in other comprehensive income			0
Changes in fair value of derivative financial instruments reclassified to income			20
Capital contributions		165
Acquisition of noncontrolling interest in subsidiary (Note 11)		0
Sale of Midcoast assets (Note 6)		0
Comprehensive income attributable to noncontrolling interests	(190)	190
Ending balance at Jun. 30, 2018	$ 6,770	$ 5,070	$ (179)	$ 224	$ 267	$ 0	$ 0	$ 774	$ 614	$ 0	$ 0	$ 0

GENERAL

GENERAL	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GENERAL	1. GENERAL The terms “we,” “our,” “us” and “Enbridge Energy Partners” as used in this report refer collectively to Enbridge Energy Partners, L.P. and its subsidiaries unless the context suggests otherwise. Those terms are used for convenience only and are not intended as a precise description of any separate legal entity within Enbridge Energy Partners. Nature of Operations We, together with our consolidated subsidiaries, provide crude oil and liquid petroleum gathering, transportation and storage services. In June 2017, we sold all of our ownership interest in our Midcoast gas gathering and processing business to our General Partner (the Midcoast Sale), which is an indirect wholly-owned subsidiary of Enbridge Inc. The sale of this ownership interest represented a strategic shift in our business and met the criteria for classification as discontinued operations, which resulted in the results of operations, cash flows and financial position of our natural gas business for the prior periods being reflected as discontinued operations. For further information refer to Note 6 - Asset Held for Sale, Dispositions and Discontinued Operations . Basis of Presentation The accompanying unaudited interim consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America (U.S. GAAP), for interim consolidated financial information and with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. They do not include all the information and notes required by U.S. GAAP for annual consolidated financial statements and should therefore be read in conjunction with our annual consolidated financial statements and notes presented in our Annual Report on Form 10-K for the year ended December 31, 2017. In the opinion of management, the interim consolidated financial statements contain all adjustments, consisting only of normal recurring adjustments, necessary to present fairly our financial position, results of operations and cash flows for the interim periods reported. These interim consolidated financial statements follow the same significant accounting policies as those included in our annual consolidated financial statements for the year ended December 31, 2017, except for the adoption of new standards. Our operations and earnings for interim periods can be affected by seasonal fluctuations in the supply of and the demand for crude oil, as well as other factors such as the timing and completion of our construction projects, the effect of environmental costs and related insurance recoveries on our Lakehead System, the impact of forward commodity prices and differentials on derivative financial instruments that are accounted for at fair value and may not be indicative of annual results.

CHANGES IN ACCOUNTING POLICIES

CHANGES IN ACCOUNTING POLICIES	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
CHANGES IN ACCOUNTING POLICY	2. CHANGES IN ACCOUNTING POLICIES Adoption of New Standards Clarifying Guidance on Derecognition and Partial Sales of Nonfinancial Assets Effective January 1, 2018, we adopted Accounting Standards Update (ASU) 2017-05 on a modified retrospective basis. The new standard clarifies the scope provisions of nonfinancial assets and how to allocate consideration to each distinct asset upon sale or partial sale and amends the guidance for derecognition of a distinct nonfinancial asset in partial sale transactions so that an in-scope partial sale results in the recognition of a full gain or loss. The adoption of this accounting update did not have a material impact on our consolidated financial statements. Clarifying the Presentation of Restricted Cash in the Statement of Cash Flows Effective January 1, 2018, we adopted ASU 2016-18 on a retrospective basis. The new standard clarifies guidance on the classification and presentation of changes in restricted cash and restricted cash equivalents within the statement of cash flows. The amendments require that changes in restricted cash and restricted cash equivalents be included within cash and cash equivalents when reconciling the opening and closing period amounts shown on the statement of cash flows. For current and comparative periods, we amended the presentation in our consolidated statements of cash flows to include restricted cash and restricted cash equivalents with cash and cash equivalents. Simplifying Cash Flow Classification Effective January 1, 2018, we adopted ASU 2016-15 on a retrospective basis. The new standard reduces diversity in practice of how certain cash receipts and cash payments are classified in the statements of cash flows. The new guidance addresses eight specific presentation issues. We assessed each of the eight specific presentation issues and the adoption of this ASU did not have a material impact on our consolidated financial statements. Revenues from Contracts with Customers Effective January 1, 2018, we adopted ASU 2014-09 on a modified retrospective basis to contracts that were not yet completed at the date of initial application. The new standard was issued with the intent of significantly enhancing consistency and comparability of revenue recognition practices across entities and industries. The new standard establishes a single, principles-based five-step model to be applied to all contracts with customers and introduces new and enhanced disclosure requirements. It also requires the use of more estimates and judgments, as well as additional disclosures. The adoption of this new standard did not have a material impact on our consolidated financial statements, see Note 3 - Revenue for further details. Future Accounting Policy Changes Improvements to Accounting for Hedging Activities ASU 2017-12 was issued in August 2017 with the objective of better aligning an organization's risk management activities and the resulting hedge accounting reflected in the financial statements. The amendments allow cash flow hedging of contractually specified components in financial and non-financial items. Under the new guidance, hedge ineffectiveness is no longer required to be measured and hedging instruments’ fair value changes will be recorded in the same income statement line as the hedged item. The ASU also allows the initial quantitative hedge effectiveness assessment to be performed at any time before the end of the quarter in which the hedge is designated. After initial quantitative testing is performed, an ongoing qualitative effectiveness assessment is permitted. The accounting update is effective January 1, 2019, with early adoption permitted and is to be applied on a modified retrospective basis. We are currently assessing the impact of the new standard on the consolidated financial statements. Accounting for Credit Losses ASU 2016-13 was issued in June 2016 with the intent of providing financial statement users with more useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. Current treatment uses the incurred loss methodology for recognizing credit losses that delays the recognition until it is probable a loss has been incurred. The accounting update adds a new impairment model, known as the current expected credit loss model, which is based on expected losses rather than incurred losses. Under the new guidance, an entity will recognize as an allowance its estimate of expected credit losses, which the Financial Accounting Standards Board believes will result in more timely recognition of such losses. The accounting update is effective January 1, 2020. We are currently assessing the impact of the new standard on our consolidated financial statements. Recognition of Leases ASU 2016-02 was issued in February 2016 with the intent to increase transparency and comparability among organizations. It requires lessees of operating lease arrangements to recognize lease assets and lease liabilities on the statement of financial position and disclose additional key information about lease agreements. The accounting update also replaces the current definition of a lease and requires that an arrangement be recognized as a lease when a customer has the right to obtain substantially all of the economic benefits from the use of an asset, as well as the right to direct the use of the asset. We will adopt the new standard on January 1, 2019 and we intend to apply the transition practical expedients offered in connection with this update. The election to apply the package of practical expedients allows an entity to not apply the new lease standard to the prior year comparative periods in the year of adoption. Application of the package of practical expedients permits entities not to reassess whether any expired or existing contracts contain leases, their lease classification, as well as any related initial direct costs. Further, ASU 2018-01 was issued in January 2018 to address stakeholder concerns about the costs and complexity of complying with the transition provisions of the new lease requirements as they relate to land easements. The amendments provide an optional transition practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under existing guidance. We intend to elect this practical expedient in connection with the adoption of the new lease requirements. We have substantially completed the process of identifying existing lease contracts and are currently performing detailed evaluations of our leases under the new accounting requirements. We believe the most significant changes to our financial statements relate to the recognition of a lease liability and offsetting right-of-use asset in our consolidated statements of financial position for operating leases. We continue to assess the necessary changes to accounting and business processes in order to implement the recognition and disclosure requirements of the new lease standard.

REVENUE

REVENUE	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
REVENUE	3. REVENUE Revenues from Contracts with Customers Major Products and Services Three months ended June 30, Six months ended June 30, 2018 2018 (in millions) Operating revenues: Transportation $ 519 $ 1,090 Storage and other 25 49 Total revenues from contracts with customers 544 1,139 Other (7 ) (10 ) Total revenues $ 537 $ 1,129 Recognition and Measurement of Revenue Three months ended June 30, Six months ended June 30, 2018 2018 2018 (in millions) Revenues from products and services transferred over time - crude oil pipeline transportation and storage $ 544 $ 1,139 Payment terms Payments are received monthly from customers under long-term transportation contracts. Contract balances Contract assets represent the amount of revenue which has been recognized in advance of payments received for performance obligations we have fulfilled (or partially fulfilled) and prior to the point in time at which our right to the payment is unconditional. Amounts included in contract assets are transferred to accounts receivable when our right to the consideration becomes unconditional. Contract liabilities represent payments received for performance obligations which have not been fulfilled. Contract liabilities primarily relate to make-up rights. We had Receivables balances of $255 million and $217 million at January 1, 2018 and June 30, 2018, respectively. At June 30, 2018, we had no material contract assets and $4 million in contract liabilities. Revenues to be Recognized from Unfulfilled Performance Obligations Total revenues from performance obligations expected to be fulfilled in future periods is $567 million , of which $62 million and $128 million are expected to be recognized during the remaining six months ending December 31, 2018 and for the year ended December 31, 2019, respectively. Certain revenues such as flow-through operating costs charged to shippers are recognized at the amount for which we have the right to invoice our customers. Those revenues are not included in the amounts for revenues to be recognized in the future from unfulfilled performance obligations above. Variable consideration is excluded from the amounts above due to the uncertainty of the associated consideration, which is generally resolved when actual volumes and prices are determined. Additionally, the effect of escalation on certain tolls which are contractually escalated for inflation has not been reflected in the amounts above as it is not possible to reliably estimate future inflation rates. Finally, revenues from contracts with customers which have an original expected duration of one year or less are excluded from the amounts above. Significant Judgments made in Recognizing Revenues Judgment is required in estimating variable consideration for volumetric transportation and sales contracts. We estimate variable consideration for these contracts as the most likely amount based on actual volumes transported and delivered when those quantities are determined at the conclusion of each month using metered volumes and actual average monthly index prices for commodity sales contracts.

NET INCOME PER LIMITED PARTNER

NET INCOME PER LIMITED PARTNER UNIT	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
NET INCOME PER LIMITED PARTNER UNIT	4. NET INCOME PER LIMITED PARTNER UNIT We determined basic and diluted net income per limited partner unit as follows: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions, except per unit amounts) Continuing operations: Net income $ 187 $ 232 $ 359 $ 411 Noncontrolling interests (92 ) (102 ) (190 ) (178 ) Series 1 preferred unit distributions — (6 ) — (29 ) Accretion of discount on Series 1 preferred units — (7 ) — (8 ) Net income - continuing operations 95 117 169 196 Distributions: Incentive distributions to Class F units (4 ) (4 ) (8 ) (8 ) Distributed earnings attributed to our General Partner (3 ) (3 ) (6 ) (6 ) Distributed earnings attributed to Class E units (6 ) (6 ) (13 ) (13 ) Total distributed earnings to our General Partner, Class E and Class F units (13 ) (13 ) (27 ) (27 ) Total distributed earnings attributed to our common units and i-units (151 ) (147 ) (300 ) (293 ) Total distributed earnings (164 ) (160 ) (327 ) (320 ) Overdistributed earnings $ (69 ) $ (43 ) $ (158 ) $ (124 ) Discontinued operations: Net loss $ — $ (35 ) $ — $ (57 ) Noncontrolling interest — 11 — 19 Net loss – discontinued operations $ — $ (24 ) $ — $ (38 ) Weighted average common units and i-units outstanding 428 400 427 377 Basic and diluted earnings per unit: Distributed earnings per common unit and i-unit - continuing operations (1) $ 0.35 $ 0.37 $ 0.70 $ 0.78 Overdistributed earnings per common unit and i-unit (2) (0.16 ) (0.10 ) (0.36 ) (0.32 ) Net income per common unit and i-unit (basic and diluted) - continuing operations (3) 0.19 0.27 0.34 0.46 Net loss per common unit and i-unit (basic and diluted) - discontinued operations (3) — (0.06 ) — (0.10 ) Net income per common unit and i-unit (basic and diluted) $ 0.19 $ 0.21 $ 0.34 $ 0.36 _____________________ (1) Represents the total distributed earnings to common units and i-units divided by the weighted average number of common units and i-units outstanding for the period. (2) Represents the common units’ and i-units’ share ( 98% ) of distributions in excess of earnings divided by the weighted average number of common units and i-units outstanding for the period and overdistributed earnings allocated to the common units and i-units based on the distribution waterfall that is outlined in our partnership agreement. (3) For the three and six months ended June 30, 2018 , 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per share. For the three months ended June 30, 2017 , 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per share. For the six months ended June 30, 2017 , 43.2 million anti-dilutive Preferred units and 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per unit and 66.1 million of Class D units were excluded from the if-converted method of calculating diluted earnings per unit as the General Partner irrevocably waived all of its rights associated with the Class D units effective April 27, 2017.

REGULATORY MATTERS

REGULATORY MATTERS	6 Months Ended
	Jun. 30, 2018
Regulatory Assets and Liabilities Disclosure [Abstract]
REGULATORY MATTERS	5. REGULATORY MATTERS Regulatory Accounting Our over and under recovery revenue adjustments and net regulatory asset amortization are as follows: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions) Net regulatory (liability) asset balance at beginning of period $ (11 ) $ (34 ) $ 3 $ 12 Prior period true-up — — 4 (5 ) Current period (over) under recovery revenue adjustments (21 ) 12 (37 ) (27 ) Amortization of prior year regulatory asset (2 ) (2 ) (4 ) (4 ) Net regulatory liability balance at end of period $ (34 ) $ (24 ) $ (34 ) $ (24 )

ASSET HELD FOR SALE, DISPOSITIO

ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS	6. ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS Asset Held for Sale During the first quarter of 2018, we satisfied the conditions as set out in our agreements for the sale of our Line 10 crude oil pipeline, a component of our Lakehead System. Line 10 originates near Hamilton, Ontario and terminates at West Seneca, New York. We own the United States portion of Line 10, while a subsidiary of the indirect parent of our General Partner, Enbridge Inc., (Enbridge) owns the Canadian portion. We expect to close the sale of Line 10 within one year, subject to regulatory approval and certain closing conditions. As such, we classified our portion of Line 10 assets as held for sale and measured them at the lower of their carrying value or fair value less costs to sell, which resulted in a loss of $36 million included within “Impairment of long-lived asset” on our consolidated statements of income for the six months ended June 30, 2018. The remaining held for sale assets and liabilities were not material. Dispositions During the second quarter of 2017, we sold unnecessary pipe related to the Sandpiper Project for cash proceeds of approximately $98 million . A gain on disposition of $51 million was included in "Gain on sale of assets" on our consolidated statements of income. In March 2017, we completed the sale of the Ozark Pipeline to a subsidiary of MPLX LP for cash proceeds of approximately $220 million , including reimbursement costs. A gain on disposition of $11 million was included in “Gain on sale of assets” on our consolidated statements of income. Discontinued Operations Sale of Natural Gas Business In June 2017, we completed the sale of all of our ownership interest in our Midcoast gas gathering and processing business to our General Partner for $2.3 billion , which included cash consideration of $1.3 billion and outstanding indebtedness at Midcoast Energy Partners, L.P. (MEP) of $953 million . This sale included our 48.4% limited partnership interest in Midcoast Operating, L.P., our 51.9% limited partnership interest in MEP, and our 100% interest in Midcoast Holdings, L.L.C., MEP’s general partner. We recorded no gain or loss on the sale as this transaction was between entities under common control of Enbridge. The carrying value of the net assets sold was $4.3 billion . As a result of the transaction, partners’ capital decreased by $2.1 billion , all of which was allocated to the General Partner’s capital account. Noncontrolling interest (NCI) in MEP of $297 million was eliminated. The following table presents the operating results from discontinued operations of our Midcoast gas gathering and processing business, which have been segregated from our continuing operations in our consolidated statements of income: Three months ended June 30, Six months ended June 30, 2017 2017 (in millions) Operating revenues $ 587 $ 1,161 Operating expenses: Commodity costs 523 1,011 Operating and administrative 63 133 Depreciation and amortization 37 74 623 1,218 Operating loss (36 ) (57 ) Interest expense, net 9 17 Other income 10 18 Loss before income taxes (35 ) (56 ) Income tax expense — (1 ) Loss from discontinued operations, net of taxes $ (35 ) $ (57 )

EQUITY INVESTMENT IN JOINT VENT

EQUITY INVESTMENT IN JOINT VENTURE	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
EQUITY INVESTMENT IN JOINT VENTURE	7. EQUITY INVESTMENT IN JOINT VENTURE The following table presents our equity investment in a joint venture and ownership interest in MarEn Bakken Company LLC (MarEn). Ownership Interest June 30, December 31, (in millions) MarEn Bakken Company LLC 75% $1,530 $1,565 In February 2017, our joint venture with Marathon Petroleum Corporation (MPC), MarEn, closed its acquisition to acquire a 49% interest in Bakken Pipeline Investments LLC (BPI). BPI owns 75% of the Dakota Access Pipeline (DAPL) and the Energy Transfer Crude Oil Pipeline (ETCOP), collectively the Bakken Pipeline System. The Bakken Pipeline System was placed into service June 1, 2017. Our investment subsidiary, Enbridge Holdings (DakTex) L.L.C. (DakTex) and MPC indirectly hold 75% and 25% interests, respectively, of MarEn. The purchase of DakTex's effective 27.6% interest in the Bakken Pipeline System was $1.5 billion and funded through a bridge loan from Enbridge (U.S.) Inc., (EUS) an affiliate of our General Partner and was re-paid and terminated on April 27, 2017, as a result of the finalization by our Board of Directors of a joint funding arrangement with our General Partner. This arrangement resulted in DakTex now being owned 75% by our General Partner and 25% by us. Refer to Note 11 - Related Party Transactions for further details on our joint funding arrangements. We account for our investment in MarEn under the equity method of accounting. For the three and six months ended June 30, 2018 , we recognized $33 million and $56 million , respectively and $6 million for the six months ended June 30, 2017 , in “Income from equity investment in joint venture" in our consolidated statements of income representing our equity earnings for this investment, net of amortization of the excess of the purchase price over the underlying net book value (basis difference). Our equity investment includes basis difference of the investees’ assets at the purchase date, which is comprised of $14 million in goodwill and $931 million in amortizable assets. We amortized $9 million and $19 million , respectively, for the three and six months ended June 30, 2018 and $3 million for the six months June 30, 2017 , which was recorded as a reduction to equity earnings.

DEBT

DEBT	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
DEBT	8. DEBT Credit Facilities Maturity Dates (1) Total Facilities (2) Draws (3) Available (in millions) Enbridge Energy Partners, L.P. 2019 – 2022 $2,625 $1,719 $906 _______________________ (1) Includes $175 million and $185 million of commitments that expire in 2018 and 2020, respectively. (2) Includes our $2.0 billion multi-year revolving credit facility (Credit Facility) and our $625 million credit agreement (364-Day Credit Facility), together (the Credit Facilities). (3) Includes facility draws, letters of credit and commercial paper issuances that are back-stopped by the credit facility and excludes our unsecured revolving 364-day credit agreement with EUS (the EUS 364-day Credit Facility). Our commercial paper program provides for the issuance of up to an aggregate principal amount of $1.5 billion of commercial paper and is supported by the availability of long-term committed credit facilities, and therefore is classified as long-term debt as of June 30, 2018 and December 31, 2017, respectively. In addition to the committed credit facilities noted in the above table, we also have $175 million available under an uncommitted letters of credit arrangement, of which $172 million and $174 million were unutilized as of June 30, 2018 and December 31, 2017 , respectively. Our Credit Facilities, had net borrowings of approximately $175 million as of June 30, 2018 , which includes gross borrowings of $1,117 million and gross repayments of $942 million . Under our commercial paper program, we had net borrowings of approximately $91 million as of June 30, 2018 , which includes gross borrowings of $10.9 billion and gross repayments of $10.8 billion . On April 15, 2018, our 6.5% senior notes of $400 million matured, and were subsequently paid on April 16, 2018. On June 29, 2018, we extended the termination date attributable to our 364-Day Credit Facility to December 31, 2018, which has a term out option that could extend maturity of any outstanding borrowings to December 31, 2019. The size of the facility remains at $625 million and is through a syndicate of third party lenders. Debt Covenants We and our consolidated subsidiaries were in compliance with the terms of our financial covenants under our consolidated debt agreements as of June 30, 2018 . Fair Value of Debt Obligations The carrying amounts of our outstanding commercial paper, borrowings under our Credit Facilities, and the EUS 364-day Credit Facility approximate their fair values due to the short-term nature and frequent repricing of the amounts outstanding under these obligations. The fair value of our outstanding commercial paper and borrowings under our Credit Facilities and the EUS 364-day Credit Facility are included with our long-term debt obligations above since we have the ability and the intent to refinance the amounts outstanding on a long-term basis. The approximate fair value of our fixed-rate debt obligations was $5.2 billion and $5.8 billion as of June 30, 2018 and December 31, 2017 , respectively. We determined the approximate fair values using a standard methodology that incorporates pricing points that are obtained from independent, third-party investment dealers who actively make markets in our debt securities. We use these pricing points to calculate the present value of the principal obligation to be repaid at maturity and all future interest payment obligations for any debt outstanding. The fair value of our long-term debt obligations is categorized as Level 2 within the fair value hierarchy.

NONCONTROLLING INTERESTS

NONCONTROLLING INTERESTS	6 Months Ended
	Jun. 30, 2018
Noncontrolling Interest [Abstract]
NONCONTROLLING INTERESTS	9. NONCONTROLLING INTERESTS The following table presents income attributable to our noncontrolling interests as outlined below: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions) Eastern Access $ 27 $ 37 $ 61 $ 77 U.S. Mainline Expansion 27 36 62 69 North Dakota Pipeline Company — 18 — 16 U.S. Line 3 Replacement Program 13 6 25 11 Enbridge Holdings (DakTex) L.L.C. 25 5 42 5 Midcoast Energy Partners, L.P. – discontinued operations — (11 ) — (19 ) Total $ 92 $ 91 $ 190 $ 159

PARTNERS' CAPITAL

PARTNERS' CAPITAL	6 Months Ended
	Jun. 30, 2018
Partners' Capital Notes [Abstract]
PARTNERS’ CAPITAL	10. PARTNERS' CAPITAL Curing Our limited partnership agreement does not permit capital deficits to accumulate in the capital accounts of any limited partner and thus requires that such capital account deficits be “cured” by additional allocations from the positive capital accounts of the common units, i-units, and our General Partner, generally on a pro-rated basis. For the six months ended June 30, 2018 , the carrying amounts for the capital accounts of the Class B common units were reduced below zero due to distributions to limited partners in excess of earnings and were subsequently cured. Class A common units and i-units had positive capital balances and therefore, as outlined in the partnership agreement, we allocated earnings of $158 million to our General Partner to recover previous curing allocations made by the General Partner. Redemption of Series 1 Preferred Units In April 2017, we redeemed all of our outstanding Series 1 Preferred Units held by our General Partner at face value of $1.2 billion in cash. The remaining unamortized beneficial conversion feature discount of $9 million was recorded against the capital balance of the General Partner. Additionally, we repaid $357 million in deferred distributions on the Series 1 Preferred Units owed to our General Partner upon the closing of the Midcoast sale. Issuance of Class A Units In April 2017, we funded the redemption of the Series 1 Preferred Units through the issuance of 64.3 million Class A common units to our General Partner at a price of $18.66 per Class A common unit. The Class A common units were recognized at fair value. The fair value of the Class A common units was $18.57 per unit, resulting in a $1.2 billion increase to the Class A common units capital account. Simplification of Incentive Distributions In April 2017, a wholly-owned subsidiary of our General Partner irrevocably waived all of its rights associated with its 66.1 million Class D units and 1,000 incentive distribution units (IDU), in exchange for the issuance of 1,000 Class F units. The waiver represented an extinguishment, resulting in a derecognition of the Class D units and IDUs at their respective carrying values. The Class F units were recorded at their fair value using the income approach on the basis of discounted cash flow from expected quarterly distributions of $263 million with the difference between the fair value of the Class F units and the carrying value of the Class D units and IDUs being recorded as an increase of $2.7 billion to our General Partner's capital accounts.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	11. RELATED PARTY TRANSACTIONS Administrative and Workforce Related Services We do not directly employ any of the individuals responsible for managing or operating our business nor do we have any directors. Enbridge and its affiliates provide management and we obtain managerial, administrative, operational and workforce related services from our General Partner, Enbridge Management and affiliates of Enbridge pursuant to service agreements among our General Partner, Enbridge Management, affiliates of Enbridge, and us. Pursuant to these service agreements, we have agreed to reimburse our General Partner, Enbridge Management and affiliates of Enbridge, for the cost of managerial, administrative, operational and director services they provide to us. Where directly attributable, the cost of all compensation, benefits expenses and employer expenses for these employees are charged directly by Enbridge to the appropriate affiliate. Enbridge does not record any profit or margin for the administrative and operational services charged to us. The affiliate amounts incurred by us for services received pursuant to the services agreements are reflected in “Operating and administrative - affiliate” on our consolidated statements of income. Enbridge and its affiliates allocated direct workforce costs to us for our construction projects of $5 million and $17 million as of June 30, 2018 and December 31, 2017, respectively, which we recorded as additions to “Property, plant and equipment, net” on our consolidated statements of financial position. Affiliate Revenues We record operating revenues for storage, transportation and terminalling services we provide to affiliates, which are presented in “Transportation and other services - affiliate” on our consolidated statements of income. Financial Transactions with Affiliates EUS 364-day Credit Facility We are party to the EUS 364-day Credit Facility, with EUS. The EUS 364-day Credit Facility is a committed senior unsecured revolving credit facility that permits aggregate borrowings of up to, $750 million . As of June 30, 2018 , we had $750 million outstanding under this facility, excluding any accrued interest to date. Joint Funding Arrangement for Bakken Pipeline System We have a joint funding arrangement with our General Partner which established ownership in the Class A units of DakTex, the entity through which we and our General Partner own our interest in MarEn. Our General Partner owns a 75% interest and we own a 25% interest in DakTex, with an option for us to increase our interest by 20% at a price equal to net book value, at any time during the five years subsequent to the June 1, 2017 in-service date of the Bakken Pipeline System. Our General Partner made contributions to DakTex totaling $4 million and $14 million , respectively, for the six months ended June 30, 2018 and 2017 , respectively. During the second quarter of 2017 we received distributions from DakTex in the amount of $1.1 billion . The funds received, along with additional borrowing under the EUS 364-day Credit Facility, were used to repay a bridge loan from EUS which was subsequently terminated. Equity income for the three and six months ended June 30, 2018 , was $33 million and $56 million , respectively and $6 million for the six months ended June 30, 2017 , of which 75% is attributable to our General Partner and recorded as part of NCI. Joint Funding Arrangement for U.S. Line 3 Replacement Program We have a joint funding arrangement with our General Partner for the U.S. Line 3 Replacement Program (U.S. L3R Program). Under the terms of the arrangement, our General Partner funds 99% and we fund 1% of the capital cost of the U.S. L3R Program. We have an option to increase our interest in the U.S. L3R Program assets up to 40% in the U.S. portion at book value at any time up to four years after the project goes into service. Our General Partner paid $450 million for its 99% interest in the project in January 2017, including our share of the construction costs and other incremental amounts. The carrying amount of our General Partner's 99% interest in the project was recorded as an increase to noncontrolling interest. The $40 million difference between the cash received and the carrying amount was recorded as an increase to the capital accounts of our common units, i-units, and General Partner interest on a pro-rated basis. Our General Partner made contributions to Enbridge Energy, Limited Partnership (OLP) totaling $155 million and $100 million for the six months ended June 30, 2018 and 2017 , respectively, to fund its portion of the construction costs associated with the U.S. L3R Program. Joint Funding Arrangement for Eastern Access Projects We have a joint funding arrangement with our General Partner that established the Series EA interests in the OLP (the EA interest), which were created to finance the Eastern Access Project to increase access to refineries in the U.S. Upper Midwest and in Ontario, Canada for light crude oil produced in western Canada and the United States. In January 2017, we exercised our option under the Eastern Access joint funding arrangement to acquire an additional 15% interest in the Eastern Access Project, thereby increasing our ownership interest from 25% to 40% and reducing the interest of our General Partner from 75% to 60% . The exercise of our option occurred at book value of approximately $360 million and reduced noncontrolling interests by approximately $360 million . The Eastern Access Project was placed into service in June 2016. Our General Partner made contributions to the OLP totaling $1 million and $6 million for the six months ended June 30, 2018 and 2017 , respectively, to fund its portion of the construction costs associated with the Eastern Access Project. Joint Funding Arrangement for U.S. Mainline Expansion Projects The OLP also has a series of partnership interests (the ME interests) which were created to finance the Mainline Expansion Projects to increase access to the markets of North Dakota and western Canada for light oil production on our Lakehead System between Neche, North Dakota and Superior, Wisconsin. Our General Partner owns 75% of the ME interests and we own 25% of the ME interests, with an option for us to increase our ownership interest by an additional 15% at cost, under the Mainline Expansion joint funding arrangement. Our General Partner made contributions to the OLP totaling $5 million and $26 million for the six months ended June 30, 2018 and 2017 , respectively, to fund its portion of the construction costs associated with the Mainline Expansion Projects. Distributions Distributions from Enbridge Holdings (DakTex) L.L.C. The following table presents distributions paid by DakTex during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in Class A units of DakTex, and to us, as the holders of the remaining Class A units of DakTex. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total DakTex Distribution (in millions) June 28, 2018 June 28, 2018 $ 11 $ 35 $ 46 April 6, 2018 April 6, 2018 12 38 50 $ 23 $ 73 $ 96 Distributions to Series EA Interests The following table presents distributions paid by the OLP during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in the Series EA, and to us, as the holders of the Series EA general partner interests and certain limited partner interests. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total Series EA Distribution (in millions) April 27, 2018 May 15, 2018 $ 32 $ 47 $ 79 January 31, 2018 February 14, 2018 34 50 84 $ 66 $ 97 $ 163 Distributions to Series ME Interests The following table presents distributions paid by the OLP during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in the Series ME, and to us, as the holders of the Series ME general partner and certain limited partner interests. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total Series ME Distribution (in millions) April 27, 2018 May 15, 2018 $ 13 $ 40 $ 53 January 31, 2018 February 14, 2018 15 44 59 $ 28 $ 84 $ 112

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	12. COMMITMENTS AND CONTINGENCIES Environmental Liabilities We are subject to federal and state laws and regulations relating to the protection of the environment. These laws and regulations can change from time to time, imposing new obligations on us. Environmental risk is inherent to liquid hydrocarbon pipeline operations, and we are, at times, subject to environmental remediation at various contaminated sites. We manage this environmental risk through environmental policies and practices to minimize any impact our operations may have on the environment. To the extent that we are unable to recover payment for environmental liabilities from insurance or other potentially responsible parties, we will be responsible for payment of liabilities arising from environmental incidents associated with the operating activities of our liquids businesses. Our General Partner has agreed to indemnify us from and against any costs relating to environmental liabilities associated with the Lakehead System assets prior to the transfer of these assets to us in 1991. This excludes any liabilities resulting from a change in laws after such transfer. We continue to voluntarily investigate past leak sites on our systems for the purpose of assessing whether any remediation is required in light of current regulations. As of June 30, 2018 and December 31, 2017 , our consolidated statements of financial position included $17 million and $ 23 million , respectively, in “Environmental liabilities,” and $ 26 million and $ 51 million , respectively, in “Other long-term liabilities,” that we have accrued for costs to address remediation of contaminated sites, asbestos containing materials, management of hazardous waste material disposal, outstanding air quality measures for certain of our liquids assets and penalties we have been or expect to be assessed. On May 31, 2018, we received a No Further Action letter from the Michigan Department of Environmental Quality and subsequently reduced our Line 6B environmental accrual by $28 million . Legal and Regulatory Proceedings We are subject to various legal and regulatory actions and proceedings that arise in the normal course of business, including interventions in regulatory proceedings and challenges to regulatory approvals and permits by special interest groups. Some of these proceedings are covered, in whole or in part, by insurance. We are in discovery in relation to a unitholder class and derivative action, with trial scheduled in the second quarter of 2019. A motion to dismiss the entirety of the action is pending. An estimate of reasonably possible losses, if any, associated with causes of action cannot be made until all of the facts, circumstances and legal theories relating to such claims and the defenses are fully disclosed and analyzed. We have not established any reserves relating to this action. We believe the action is without merit and expect to vigorously defend against it. We believe an unfavorable outcome to be more than remote but less than probable.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	13. SUBSEQUENT EVENTS Distribution to Partners On July 25, 2018 , the board of directors of Enbridge Management declared a distribution payable to our partners on August 14, 2018 . The distribution will be paid to unitholders of record as of August 7, 2018 of our available cash of $164 million at June 30, 2018 , or $0.35 per limited partner unit. Of this distribution, $130 million will be paid in cash, $33 million will be distributed in i-units to our i-unitholder, Enbridge Management, and due to the i-unit distribution, $1 million will be retained from our General Partner from amounts otherwise distributable to it in respect of its general partner interest and limited partner interest to maintain its 2% general partner interest. Distribution to Series EA Interests On July 25, 2018 the managing general partner of the Series EA interests, declared a distribution payable to the holders of the Series EA general and limited partner interests. The OLP will pay $38 million to the noncontrolling interest in the Series EA, while $26 million will be paid to us. Distribution to Series ME Interests On July 25, 2018 , the managing general partner of the Series ME interests declared a distribution payable to the holders of the Series ME general and limited partner interests. The OLP will pay $31 million to the noncontrolling interest in the Series ME, while $11 million will be paid to us.

CHANGES IN ACCOUNTING POLICIES

CHANGES IN ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Adoption of New Standards	Adoption of New Standards Clarifying Guidance on Derecognition and Partial Sales of Nonfinancial Assets Effective January 1, 2018, we adopted Accounting Standards Update (ASU) 2017-05 on a modified retrospective basis. The new standard clarifies the scope provisions of nonfinancial assets and how to allocate consideration to each distinct asset upon sale or partial sale and amends the guidance for derecognition of a distinct nonfinancial asset in partial sale transactions so that an in-scope partial sale results in the recognition of a full gain or loss. The adoption of this accounting update did not have a material impact on our consolidated financial statements. Clarifying the Presentation of Restricted Cash in the Statement of Cash Flows Effective January 1, 2018, we adopted ASU 2016-18 on a retrospective basis. The new standard clarifies guidance on the classification and presentation of changes in restricted cash and restricted cash equivalents within the statement of cash flows. The amendments require that changes in restricted cash and restricted cash equivalents be included within cash and cash equivalents when reconciling the opening and closing period amounts shown on the statement of cash flows. For current and comparative periods, we amended the presentation in our consolidated statements of cash flows to include restricted cash and restricted cash equivalents with cash and cash equivalents. Simplifying Cash Flow Classification Effective January 1, 2018, we adopted ASU 2016-15 on a retrospective basis. The new standard reduces diversity in practice of how certain cash receipts and cash payments are classified in the statements of cash flows. The new guidance addresses eight specific presentation issues. We assessed each of the eight specific presentation issues and the adoption of this ASU did not have a material impact on our consolidated financial statements. Revenues from Contracts with Customers Effective January 1, 2018, we adopted ASU 2014-09 on a modified retrospective basis to contracts that were not yet completed at the date of initial application. The new standard was issued with the intent of significantly enhancing consistency and comparability of revenue recognition practices across entities and industries. The new standard establishes a single, principles-based five-step model to be applied to all contracts with customers and introduces new and enhanced disclosure requirements. It also requires the use of more estimates and judgments, as well as additional disclosures. The adoption of this new standard did not have a material impact on our consolidated financial statements, see Note 3 - Revenue for further details. Future Accounting Policy Changes Improvements to Accounting for Hedging Activities ASU 2017-12 was issued in August 2017 with the objective of better aligning an organization's risk management activities and the resulting hedge accounting reflected in the financial statements. The amendments allow cash flow hedging of contractually specified components in financial and non-financial items. Under the new guidance, hedge ineffectiveness is no longer required to be measured and hedging instruments’ fair value changes will be recorded in the same income statement line as the hedged item. The ASU also allows the initial quantitative hedge effectiveness assessment to be performed at any time before the end of the quarter in which the hedge is designated. After initial quantitative testing is performed, an ongoing qualitative effectiveness assessment is permitted. The accounting update is effective January 1, 2019, with early adoption permitted and is to be applied on a modified retrospective basis. We are currently assessing the impact of the new standard on the consolidated financial statements. Accounting for Credit Losses ASU 2016-13 was issued in June 2016 with the intent of providing financial statement users with more useful information about the expected credit losses on financial instruments and other commitments to extend credit held by a reporting entity at each reporting date. Current treatment uses the incurred loss methodology for recognizing credit losses that delays the recognition until it is probable a loss has been incurred. The accounting update adds a new impairment model, known as the current expected credit loss model, which is based on expected losses rather than incurred losses. Under the new guidance, an entity will recognize as an allowance its estimate of expected credit losses, which the Financial Accounting Standards Board believes will result in more timely recognition of such losses. The accounting update is effective January 1, 2020. We are currently assessing the impact of the new standard on our consolidated financial statements. Recognition of Leases ASU 2016-02 was issued in February 2016 with the intent to increase transparency and comparability among organizations. It requires lessees of operating lease arrangements to recognize lease assets and lease liabilities on the statement of financial position and disclose additional key information about lease agreements. The accounting update also replaces the current definition of a lease and requires that an arrangement be recognized as a lease when a customer has the right to obtain substantially all of the economic benefits from the use of an asset, as well as the right to direct the use of the asset. We will adopt the new standard on January 1, 2019 and we intend to apply the transition practical expedients offered in connection with this update. The election to apply the package of practical expedients allows an entity to not apply the new lease standard to the prior year comparative periods in the year of adoption. Application of the package of practical expedients permits entities not to reassess whether any expired or existing contracts contain leases, their lease classification, as well as any related initial direct costs. Further, ASU 2018-01 was issued in January 2018 to address stakeholder concerns about the costs and complexity of complying with the transition provisions of the new lease requirements as they relate to land easements. The amendments provide an optional transition practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under existing guidance. We intend to elect this practical expedient in connection with the adoption of the new lease requirements. We have substantially completed the process of identifying existing lease contracts and are currently performing detailed evaluations of our leases under the new accounting requirements. We believe the most significant changes to our financial statements relate to the recognition of a lease liability and offsetting right-of-use asset in our consolidated statements of financial position for operating leases. We continue to assess the necessary changes to accounting and business processes in order to implement the recognition and disclosure requirements of the new lease standard.

REVENUE (Tables)

REVENUE (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	Major Products and Services Three months ended June 30, Six months ended June 30, 2018 2018 (in millions) Operating revenues: Transportation $ 519 $ 1,090 Storage and other 25 49 Total revenues from contracts with customers 544 1,139 Other (7 ) (10 ) Total revenues $ 537 $ 1,129 Three months ended June 30, Six months ended June 30, 2018 2018 2018 (in millions) Revenues from products and services transferred over time - crude oil pipeline transportation and storage $ 544 $ 1,139

NET INCOME PER LIMITED PARTNE23

NET INCOME PER LIMITED PARTNER UNIT (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Basic and Diluted Net Income Per Limited Partner Unit	We determined basic and diluted net income per limited partner unit as follows: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions, except per unit amounts) Continuing operations: Net income $ 187 $ 232 $ 359 $ 411 Noncontrolling interests (92 ) (102 ) (190 ) (178 ) Series 1 preferred unit distributions — (6 ) — (29 ) Accretion of discount on Series 1 preferred units — (7 ) — (8 ) Net income - continuing operations 95 117 169 196 Distributions: Incentive distributions to Class F units (4 ) (4 ) (8 ) (8 ) Distributed earnings attributed to our General Partner (3 ) (3 ) (6 ) (6 ) Distributed earnings attributed to Class E units (6 ) (6 ) (13 ) (13 ) Total distributed earnings to our General Partner, Class E and Class F units (13 ) (13 ) (27 ) (27 ) Total distributed earnings attributed to our common units and i-units (151 ) (147 ) (300 ) (293 ) Total distributed earnings (164 ) (160 ) (327 ) (320 ) Overdistributed earnings $ (69 ) $ (43 ) $ (158 ) $ (124 ) Discontinued operations: Net loss $ — $ (35 ) $ — $ (57 ) Noncontrolling interest — 11 — 19 Net loss – discontinued operations $ — $ (24 ) $ — $ (38 ) Weighted average common units and i-units outstanding 428 400 427 377 Basic and diluted earnings per unit: Distributed earnings per common unit and i-unit - continuing operations (1) $ 0.35 $ 0.37 $ 0.70 $ 0.78 Overdistributed earnings per common unit and i-unit (2) (0.16 ) (0.10 ) (0.36 ) (0.32 ) Net income per common unit and i-unit (basic and diluted) - continuing operations (3) 0.19 0.27 0.34 0.46 Net loss per common unit and i-unit (basic and diluted) - discontinued operations (3) — (0.06 ) — (0.10 ) Net income per common unit and i-unit (basic and diluted) $ 0.19 $ 0.21 $ 0.34 $ 0.36 _____________________ (1) Represents the total distributed earnings to common units and i-units divided by the weighted average number of common units and i-units outstanding for the period. (2) Represents the common units’ and i-units’ share ( 98% ) of distributions in excess of earnings divided by the weighted average number of common units and i-units outstanding for the period and overdistributed earnings allocated to the common units and i-units based on the distribution waterfall that is outlined in our partnership agreement. (3) For the three and six months ended June 30, 2018 , 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per share. For the three months ended June 30, 2017 , 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per share. For the six months ended June 30, 2017 , 43.2 million anti-dilutive Preferred units and 18.1 million anti-dilutive Class E units were excluded from the if-converted method of calculating diluted earnings per unit and 66.1 million of Class D units were excluded from the if-converted method of calculating diluted earnings per unit as the General Partner irrevocably waived all of its rights associated with the Class D units effective April 27, 2017.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	6 Months Ended
	Jun. 30, 2018
Regulatory Assets and Liabilities Disclosure [Abstract]
Schedule of Changes in Net Regulatory Asset Balance	Our over and under recovery revenue adjustments and net regulatory asset amortization are as follows: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions) Net regulatory (liability) asset balance at beginning of period $ (11 ) $ (34 ) $ 3 $ 12 Prior period true-up — — 4 (5 ) Current period (over) under recovery revenue adjustments (21 ) 12 (37 ) (27 ) Amortization of prior year regulatory asset (2 ) (2 ) (4 ) (4 ) Net regulatory liability balance at end of period $ (34 ) $ (24 ) $ (34 ) $ (24 )

ASSET HELD FOR SALE, DISPOSIT25

ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS (Tables)	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	The following table presents the operating results from discontinued operations of our Midcoast gas gathering and processing business, which have been segregated from our continuing operations in our consolidated statements of income: Three months ended June 30, Six months ended June 30, 2017 2017 (in millions) Operating revenues $ 587 $ 1,161 Operating expenses: Commodity costs 523 1,011 Operating and administrative 63 133 Depreciation and amortization 37 74 623 1,218 Operating loss (36 ) (57 ) Interest expense, net 9 17 Other income 10 18 Loss before income taxes (35 ) (56 ) Income tax expense — (1 ) Loss from discontinued operations, net of taxes $ (35 ) $ (57 )

EQUITY INVESTMENT IN JOINT VE26

EQUITY INVESTMENT IN JOINT VENTURE (Tables)	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	The following table presents our equity investment in a joint venture and ownership interest in MarEn Bakken Company LLC (MarEn). Ownership Interest June 30, December 31, (in millions) MarEn Bakken Company LLC 75% $1,530 $1,565

DEBT (Tables)

DEBT (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	Credit Facilities Maturity Dates (1) Total Facilities (2) Draws (3) Available (in millions) Enbridge Energy Partners, L.P. 2019 – 2022 $2,625 $1,719 $906 _______________________ (1) Includes $175 million and $185 million of commitments that expire in 2018 and 2020, respectively. (2) Includes our $2.0 billion multi-year revolving credit facility (Credit Facility) and our $625 million credit agreement (364-Day Credit Facility), together (the Credit Facilities). (3) Includes facility draws, letters of credit and commercial paper issuances that are back-stopped by the credit facility and excludes our unsecured revolving 364-day credit agreement with EUS (the EUS 364-day Credit Facility).

NONCONTROLLING INTERESTS (Table

NONCONTROLLING INTERESTS (Tables)	6 Months Ended
	Jun. 30, 2018
Noncontrolling Interest [Abstract]
Schedule of Non Controlling Interest	The following table presents income attributable to our noncontrolling interests as outlined below: Three months ended June 30, Six months ended June 30, 2018 2017 2018 2017 (in millions) Eastern Access $ 27 $ 37 $ 61 $ 77 U.S. Mainline Expansion 27 36 62 69 North Dakota Pipeline Company — 18 — 16 U.S. Line 3 Replacement Program 13 6 25 11 Enbridge Holdings (DakTex) L.L.C. 25 5 42 5 Midcoast Energy Partners, L.P. – discontinued operations — (11 ) — (19 ) Total $ 92 $ 91 $ 190 $ 159

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Schedule of Distributions	The following table presents distributions paid by the OLP during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in the Series ME, and to us, as the holders of the Series ME general partner and certain limited partner interests. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total Series ME Distribution (in millions) April 27, 2018 May 15, 2018 $ 13 $ 40 $ 53 January 31, 2018 February 14, 2018 15 44 59 $ 28 $ 84 $ 112 The following table presents distributions paid by the OLP during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in the Series EA, and to us, as the holders of the Series EA general partner interests and certain limited partner interests. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total Series EA Distribution (in millions) April 27, 2018 May 15, 2018 $ 32 $ 47 $ 79 January 31, 2018 February 14, 2018 34 50 84 $ 66 $ 97 $ 163 The following table presents distributions paid by DakTex during the six months ended June 30, 2018 , to our General Partner and its affiliate, representing the noncontrolling interest in Class A units of DakTex, and to us, as the holders of the remaining Class A units of DakTex. Distribution Declaration Date Distribution Payment Date Amount Paid to EEP Amount Paid to noncontrolling Interest Total DakTex Distribution (in millions) June 28, 2018 June 28, 2018 $ 11 $ 35 $ 46 April 6, 2018 April 6, 2018 12 38 50 $ 23 $ 73 $ 96

REVENUE (Details)

REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Jan. 01, 2018
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 544		$ 1,139
Other Revenue	(7)		(10)
Revenues	537	$ 596	1,129	$ 1,201
Accounts receivables	217		217		$ 255
Contract with customer, liability	4		4
Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	519		1,090
Storage and Other Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	25		49
Transferred over Time [Member]
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 544		$ 1,139

REVENUE - Narrative (Details)

REVENUE - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 567
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 62
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue from Contract with Customer [Abstract]
Revenue, remaining performance obligation	$ 128
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year

NET INCOME PER LIMITED PARTNE32

NET INCOME PER LIMITED PARTNER UNIT (Basic and Diluted Net Income Per Limited Partner Unit) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	Apr. 27, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Continuing operations:
Income from continuing operations		$ 187	$ 232	$ 359	$ 411
Less: Net income attributable to: Noncontrolling interest		(92)	(102)	(190)	(178)
Series 1 preferred unit distributions		0	(6)	0	(29)
Accretion of discount on Series 1 preferred units		0	(7)	0	(8)
Net income - continuing operations		95	117	169	196
Distributions:
Incentive distributions		(4)	(4)	(8)	(8)
Distributed earnings attributed to Class D and Class E units		(13)	(13)	(27)	(27)
Total distributed earnings attributed to our common units and i-units		(151)	(147)	(300)	(293)
Total distributed earnings		(164)	(160)	(327)	(320)
Overdistributed earnings		(69)	(43)	(158)	(124)
Discontinued operations:
Net loss		0	(35)	0	(57)
Less: Net loss attributable to Noncontrolling interest		0	11	0	19
Net loss attributable to general and limited partner interests in Enbridge Energy Partners, L.P. - discontinued operations		$ 0	$ (24)	$ 0	$ (38)
Weighted average common units and i-units outstanding (in shares)		428	400	427	377
Basic and diluted earnings per unit:
Distributed earnings per common unit and i-unit - continuing operations (in dollars per share)		$ 0.35	$ 0.37	$ 0.70	$ 0.78
Overdistributed earnings per common unit and i-unit (in dollars per share)		(0.16)	(0.10)	(0.36)	(0.32)
Net income per common unit and i-unit (basic and diluted) - continuing operations (in dollars per share)		0.19	0.27	0.34	0.46
Net loss per common unit and i-unit (basic and diluted) - discontinued operations (in dollars per share)		0	(0.06)	0	(0.10)
Net income per common unit and i-unit (basic and diluted) (in dollars per share)		$ 0.19	$ 0.21	$ 0.34	$ 0.36
Class E Units [Member]
Distributions:
Distributed earnings attributed to Class D and Class E units		$ (6)	$ (6)	$ (13)	$ (13)
General Partner [Member]
Distributions:
Distributed earnings attributed to our General Partner		$ (3)	$ (3)	$ (6)	$ (6)
Preferred Stock [Member]
Basic and diluted earnings per unit:
Anti-dilutive Preferred Units excluded (in shares)					43.2
Class D Units [Member] | Class D Units [Member]
Basic and diluted earnings per unit:
Anti-dilutive Preferred Units excluded (in shares)	66.1
Class E Units [Member]
Basic and diluted earnings per unit:
Anti-dilutive Preferred Units excluded (in shares)		18.1	18.1	18.1	18.1
Minimum Quarterly Distribution [Member]
Basic and diluted earnings per unit:
Percentage distributed to limited partners				98.00%

REGULATORY MATTERS (Details)

REGULATORY MATTERS (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Regulatory Assets and Liabilities [Roll Forward]
Net regulatory (liability) asset balance at beginning of period	$ (11)	$ (34)	$ 3	$ 12
Prior period true-up	0	0	4	(5)
Current period (over) under recovery revenue adjustments	(21)	12	(37)	(27)
Amortization of prior year regulatory asset	(2)	(2)	(4)	(4)
Net regulatory liability balance at end of period	$ (34)	$ (24)	$ (34)	$ (24)

ASSET HELD FOR SALE, DISPOSIT34

ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended			6 Months Ended
	Jun. 28, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017
Asset impairment			$ 1	$ 0		$ 36	$ 0
Proceeds from sale of property, plant, and equipment		$ 220
Gain (loss) on disposition of assets			$ 0	51		0	$ 62
Discontinued Operations, Disposed of by Sale [Member]
Increase (decrease) in partners' capital	$ 2,100
Discontinued Operations, Disposed of by Sale [Member] | General Partners [Member]
Proceeds from divestiture of businesses	2,300
Discontinued Operations, Disposed of by Sale [Member] | Midcoast Energy Partners L.P. [Member]
Consideration transferred	1,300
Aggregate indebtedness	$ 953
Equity method investment, ownership percentage	51.90%
Asset held for sale at carrying value	$ 4,300
Noncontrolling interest in limited partnerships	$ 297
Discontinued Operations, Disposed of by Sale [Member] | Midcoast Operating L.P. [Member]
Equity method investment, ownership percentage	48.40%
Discontinued Operations, Disposed of by Sale [Member] | Midcoast Holding LLC [Member]
Noncontrolling interest, ownership percentage by parent (in percent)	100.00%
Line 10 Crude Oil [Member] | Discontinued Operations, Held-for-sale [Member]
Asset impairment						$ 36
Sandpiper Project [Member]
Proceeds from sale of property, plant, and equipment				98
Sandpiper Project [Member] | Liquids [Member]
Gain (loss) on disposition of assets				$ 51
Ozark Pipeline System [Member] | Liquids [Member]
Gain (loss) on disposition of assets					$ 11

ASSET HELD FOR SALE, DISPOSIT35

ASSET HELD FOR SALE, DISPOSITIONS AND DISCONTINUED OPERATIONS (Consolidated Statements of Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating expenses:
Loss from discontinued operations, net of taxes	$ 0	$ (35)	$ 0	$ (57)
Discontinued Operations, Disposed of by Sale [Member]
Operating revenues:
Operating revenues		587		1,161
Operating expenses:
Commodity costs		523		1,011
Operating and administrative		63		133
Depreciation and amortization		37		74
Operating expenses, Total		623		1,218
Operating loss		(36)		(57)
Interest expense, net		9		17
Other income		10		18
Loss before income taxes		(35)		(56)
Income tax expense		0		(1)
Loss from discontinued operations, net of taxes		$ (35)		$ (57)

EQUITY INVESTMENT IN JOINT VE36

EQUITY INVESTMENT IN JOINT VENTURE (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Equity investment in joint venture (Note 7)	$ 1,530	$ 1,565
MarEn Bakken Company LLC [Member]
Equity method investment, ownership percentage	75.00%
Equity investment in joint venture (Note 7)	$ 1,530	$ 1,565

EQUITY INVESTMENT IN JOINT VE37

EQUITY INVESTMENT IN JOINT VENTURE (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Feb. 15, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income from equity investment in joint venture (Note 7)		$ 33	$ 6	$ 56	$ 6
Reduction to equity earnings		$ 9		$ 19	$ 3
MarEn Bakken Company LLC [Member]
Percentage of voting interests acquired	49.00%
Bakken Pipeline System [Member]
Noncontrolling interest, ownership percentage by parent (in percent)	75.00%	75.00%		75.00%
Noncontrolling interest, ownership percentage by noncontrolling owners	27.60%
Consideration transferred	$ 1,500
Ownership interest in affiliate of Partnership (in percentage)				25.00%
Goodwill	14
Business combination, finite-lived intangibles	$ 931
MarEn Bakken Company LLC [Member]
Noncontrolling interest, ownership percentage by noncontrolling owners	25.00%

DEBT (Credit Facility) (Details

DEBT (Credit Facility) (Details) - USD ($)	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Committed Credit Facility [Member]
Line of credit facility, expiring in year one		$ 175,000,000
Line of credit facilit,y expiring in year three		$ 185,000,000
Revolving Credit Facility [Member]
Total Facilities	$ 2,625,000,000
Draws	1,719,000,000
Remaining borrowing capacity	906,000,000
Credit Facility [Member] | Revolving Credit Facility [Member]
Total Facilities	2,000,000,000
EUS 364-day Credit Facility [Member] | Revolving Credit Facility [Member]
Total Facilities	$ 625,000,000

DEBT (Narrative) (Details)

DEBT (Narrative) (Details) - USD ($)	Apr. 16, 2018	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Line of Credit Facility [Line Items]
Proceeds from Issuance of Commercial Paper		$ 1,500,000,000		$ 1,500,000,000
Net borrowings under facilities		175,000,000	$ (865,000,000)
Six Point Five Percent Senior Notes Due Twenty Eighteen [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate	6.50%
Fixed Rate Debt Obligations [Member]
Line of Credit Facility [Line Items]
Debt instrument, fair value disclosure		5,200,000,000		5,800,000,000
Uncommitted Demand Credit Facilities [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity of line of credit		175,000,000
Remaining borrowing capacity		172,000,000		$ 174,000,000
Credit Facility [Member]
Line of Credit Facility [Line Items]
Net borrowings under facilities		175,000,000
Proceeds from lines of credit		1,117,000,000
Repayments of lines of credit		942,000,000
364-Day Credit Facility [Member]
Line of Credit Facility [Line Items]
Net borrowings under facilities		91,000,000
Proceeds from lines of credit		10,900,000,000
Repayments of lines of credit		10,800,000,000
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity of line of credit		2,625,000,000
Remaining borrowing capacity		906,000,000
Proceeds from lines of credit		1,719,000,000
Revolving Credit Facility [Member] | EUS 364-day Credit Facility [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity of line of credit		$ 625,000,000
Senior Notes [Member] | Six Point Five Percent Senior Notes Due Twenty Eighteen [Member]
Line of Credit Facility [Line Items]
Repayments of debt	$ 400,000,000

NONCONTROLLING INTERESTS (Conso

NONCONTROLLING INTERESTS (Consolidated statements of financial position) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Comprehensive income (loss) attributable to noncontrolling interests	$ 92	$ 91	$ 190	$ 159
Eastern Access Interests [Member]
Comprehensive income (loss) attributable to noncontrolling interests	27	37	61	77
U.S. Mainline Expansion Interests [Member]
Comprehensive income (loss) attributable to noncontrolling interests	27	36	62	69
North Dakota Pipeline Company Interests [Member]
Comprehensive income (loss) attributable to noncontrolling interests	0	18	0	16
Line 3 Replacement Interests [Member]
Comprehensive income (loss) attributable to noncontrolling interests	13	6	25	11
Enbridge Holdings DakTex LLC Interests [Member]
Comprehensive income (loss) attributable to noncontrolling interests	25	5	42	5
Midcoast Energy Partners, L.P. - Discontinued Operations [Member]
Comprehensive income (loss) attributable to noncontrolling interests	$ 0	$ (11)	$ 0	$ (19)

PARTNERS' CAPITAL (Narrative) (

PARTNERS' CAPITAL (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	6 Months Ended
	Apr. 27, 2017	Jun. 30, 2018
Unamortized beneficial conversion feature discount	$ 9
Increase in general partners' capital account	2,700
General Partner [Member]
Allocations from capital accounts		$ 158
Series One Preferred Unit [Member]
Stock redeemed or called during period	1,200
General partner distributions	$ 357
Common Class A [Member]
Shares issued (in dollars per share)	$ 18.66
Fair value per share (in dollars per share)	$ 18.57
Stock issued during period	$ 1,200
Common Class A [Member] | General Partner [Member]
Stock issued during period (in shares)	64,300,000
Incentive Distribution Units [Member]
Number of units waived (in shares)	1,000
Common Class F [Member]
Common units, issued (in shares)	1,000
Limited partners' contributed capital	$ 263

RELATED PARTY TRANSACTIONS (Nar

RELATED PARTY TRANSACTIONS (Narrative) (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Long-term line of credit	$ 750,000,000
Enbridge Inc., Credit Agreement [Member]
Related Party Transaction [Line Items]
Maximum borrowing capacity of line of credit	750,000,000
Construction Project Work Force Cost Transactions [Member]
Related Party Transaction [Line Items]
Related party expenses	$ 5,000,000	$ 17,000,000

RELATED PARTY TRANSACTIONS (Joi

RELATED PARTY TRANSACTIONS (Joint Funding Arrangement Discussions) (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended
	Apr. 27, 2017	Jan. 26, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income from equity investment in joint venture (Note 7)			$ 33	$ 6	$ 56	$ 6
Acquisition of noncontrolling interest in subsidiary					360
Proceeds from noncontrolling interests					165	1,285
Line 3 Replacement [Member]
Consideration transferred		$ 450			155	100
Joint funding arrangement, parent (in percent)		99.00%
Joint funding arrangement noncontrolling interest (in percentage)		1.00%
Option to increase general partnership interest percentage (in percentage)		40.00%
Acquisition of noncontrolling interest in subsidiary					40
Bakken Pipeline Systems [Member]
Noncontrolling interest, ownership percentage by parent (in percent)	75.00%
Ownership interest in affiliate of Partnership (in percentage)	25.00%
Additional acquisitions percentages	20.00%
Consideration transferred					4	14
Eastern Access Pipeline [Member]
Consideration transferred					$ 1	6
Acquisition of noncontrolling interest in subsidiary		$ 360
Additional acquisition percentages		15.00%
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest		25.00%			40.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		75.00%			60.00%
US Mainline Expansion Interests [Member]
Noncontrolling interest, ownership percentage by parent (in percent)			75.00%		75.00%
Ownership interest in affiliate of Partnership (in percentage)					25.00%
Additional acquisition percentages					15.00%
Proceeds from noncontrolling interests					$ 5	26
General Partner [Member]
Consideration transferred					$ 0	$ 25
Proceeds from related party debt				$ 1,100

RELATED PARTY TRANSACTIONS (Dis

RELATED PARTY TRANSACTIONS (Distributions by Affiliates) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2018
Enbridge Holdings DakTex LLC Interests [Member]
Amount paid to parent			$ 23
Amount paid to noncontrolling interest			73
Total amount of distribution paid			96
Enbridge Holdings DakTex LLC Interests [Member] | Second Quarter Distribution [Member]
Amount paid to parent	$ 11
Amount paid to noncontrolling interest	35
Total amount of distribution paid	46
Enbridge Holdings DakTex LLC Interests [Member] | First Quarter Distribution [Member]
Amount paid to parent		$ 12
Amount paid to noncontrolling interest		38
Total amount of distribution paid		50
Series EA [Member]
Amount paid to parent			66
Amount paid to noncontrolling interest			97
Total amount of distribution paid			163
Series EA [Member] | Second Quarter Distribution [Member]
Amount paid to parent	32
Amount paid to noncontrolling interest	47
Total amount of distribution paid	79
Series EA [Member] | First Quarter Distribution [Member]
Amount paid to parent		34
Amount paid to noncontrolling interest		50
Total amount of distribution paid		84
U.S. Mainline Expansion Interests [Member]
Amount paid to parent			28
Amount paid to noncontrolling interest			84
Total amount of distribution paid			$ 112
U.S. Mainline Expansion Interests [Member] | Second Quarter Distribution [Member]
Amount paid to parent	13
Amount paid to noncontrolling interest	40
Total amount of distribution paid	$ 53
U.S. Mainline Expansion Interests [Member] | First Quarter Distribution [Member]
Amount paid to parent		15
Amount paid to noncontrolling interest		44
Total amount of distribution paid		$ 59

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Remaining liabilities	$ 17	$ 23
Accrual for environmental loss contingencies	26	$ 51
Accrual for environmental loss contingencies, period decrease	$ 28

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ / shares in Units, $ in Millions	Jul. 25, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Subsequent Event [Line Items]
Cash Available for Distribution		$ 164		$ 164
Cash distributions paid per limited partner unit outstanding (in dollars per share)		$ 0.35
Amount of distribution		$ 151	$ 147	300	$ 293
Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution declaration date	Jul. 25, 2018
Distribution payment date	Aug. 14, 2018
Distribution record date	Aug. 7, 2018
Total amount of distribution paid	$ 130
Percentage of Distribution Retained	2.00%
Subsequent Event [Member] | I Units [Member]
Subsequent Event [Line Items]
Amount of distribution	$ 33
Amount paid to parent	$ 1
Series EA Interests [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution declaration date	Jul. 25, 2018
Amount paid to parent	$ 38
Amount paid to the noncontrolling interest	$ 26
Series ME Interests [Member]
Subsequent Event [Line Items]
Total amount of distribution paid				112
Amount paid to parent				28
Amount paid to the noncontrolling interest				$ 84
Series ME Interests [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution declaration date	Jul. 25, 2018
Amount paid to parent	$ 31
Amount paid to the noncontrolling interest	$ 11