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Share Name | Share Symbol | Market | Type |
---|---|---|---|
Enbridge Energy, L.P. Class A Common Units (delisted) | NYSE:EEP | NYSE | Common Stock |
Price Change | % Change | Share Price | High Price | Low Price | Open Price | Shares Traded | Last Trade | |
---|---|---|---|---|---|---|---|---|
0.00 | 0.00% | 10.43 | 0 | 01:00:00 |
|
FORM 10-Q
|
x
|
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
|
o
|
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
|
|
|
|
ENBRIDGE ENERGY PARTNERS, L.P.
(Exact Name of Registrant as Specified in Its Charter)
|
||
|
|
|
Delaware
|
|
39-1715850
|
(State or Other Jurisdiction of
Incorporation or Organization)
|
|
(I.R.S. Employer
Identification No.)
|
Large accelerated filer
x
|
|
Accelerated filer
o
|
Non-accelerated filer
o
|
|
Smaller reporting company
o
|
Emerging growth company
o
|
|
|
|
|
PART I — FINANCIAL INFORMATION
|
|
|
||
|
||
|
||
|
||
|
||
|
||
|
||
|
PART II — OTHER INFORMATION
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Operating revenues:
|
|
|
|
|
|
|
|
|
|
|
|
||||
Transportation and other services
|
$
|
527
|
|
|
$
|
596
|
|
|
$
|
1,586
|
|
|
$
|
1,745
|
|
Transportation and other services - affiliates
|
33
|
|
|
20
|
|
|
103
|
|
|
72
|
|
||||
Total operating revenues
(Note 3)
|
560
|
|
|
616
|
|
|
1,689
|
|
|
1,817
|
|
||||
Operating expenses:
|
|
|
|
|
|
|
|
||||||||
Environmental costs, net of recoveries
|
4
|
|
|
1
|
|
|
(18
|
)
|
|
15
|
|
||||
Operating and administrative
|
62
|
|
|
77
|
|
|
198
|
|
|
239
|
|
||||
Operating and administrative - affiliates
|
64
|
|
|
85
|
|
|
195
|
|
|
235
|
|
||||
Power
|
83
|
|
|
81
|
|
|
235
|
|
|
221
|
|
||||
Depreciation and amortization
|
111
|
|
|
112
|
|
|
330
|
|
|
329
|
|
||||
Impairment of long-lived asset
(Note 6)
|
1
|
|
|
—
|
|
|
37
|
|
|
—
|
|
||||
Gain on sale of assets
(Note 6)
|
(22
|
)
|
|
(6
|
)
|
|
(22
|
)
|
|
(68
|
)
|
||||
Total operating expenses
|
303
|
|
|
350
|
|
|
955
|
|
|
971
|
|
||||
Operating income
|
257
|
|
|
266
|
|
|
734
|
|
|
846
|
|
||||
Interest expense, net
|
102
|
|
|
104
|
|
|
307
|
|
|
306
|
|
||||
Allowance for equity used during construction
|
16
|
|
|
12
|
|
|
48
|
|
|
33
|
|
||||
Income from equity investment in joint venture
(Note 7)
|
37
|
|
|
22
|
|
|
93
|
|
|
28
|
|
||||
Other income (expense)
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
5
|
|
||||
Income from continuing operations before income taxes
|
208
|
|
|
196
|
|
|
567
|
|
|
606
|
|
||||
Income tax benefit (expense)
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
|
1
|
|
||||
Income from continuing operations
|
207
|
|
|
196
|
|
|
566
|
|
|
607
|
|
||||
Loss from discontinued operations, net of taxes
(Note 6)
|
—
|
|
|
—
|
|
|
—
|
|
|
(57
|
)
|
||||
Net income
|
207
|
|
|
196
|
|
|
566
|
|
|
550
|
|
||||
Noncontrolling interests
(Note 10)
|
(103
|
)
|
|
(103
|
)
|
|
(293
|
)
|
|
(262
|
)
|
||||
Series 1 Preferred unit distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
(29
|
)
|
||||
Accretion of discount on Series 1 Preferred units
|
—
|
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
||||
Net income - controlling interests
|
$
|
104
|
|
|
$
|
93
|
|
|
$
|
273
|
|
|
$
|
251
|
|
Net income allocable to common units and i-units:
|
|
|
|
|
|
|
|
||||||||
Income from continuing operations
|
$
|
92
|
|
|
$
|
82
|
|
|
$
|
237
|
|
|
$
|
254
|
|
Loss from discontinued operations
(Note 4)
|
—
|
|
|
—
|
|
|
—
|
|
|
(38
|
)
|
||||
Net income allocable to common units and i-units
|
$
|
92
|
|
|
$
|
82
|
|
|
$
|
237
|
|
|
$
|
216
|
|
Net income per common unit and i-unit (basic and diluted):
|
|
|
|
|
|
|
|
||||||||
Income from continuing operations
(Note 4)
|
$
|
0.21
|
|
|
$
|
0.19
|
|
|
$
|
0.55
|
|
|
$
|
0.65
|
|
Loss from discontinued operations
(Note 4)
|
—
|
|
|
—
|
|
|
—
|
|
|
(0.10
|
)
|
||||
Net income per common unit and i-unit
(Note 4)
|
$
|
0.21
|
|
|
$
|
0.19
|
|
|
$
|
0.55
|
|
|
$
|
0.55
|
|
Weighted average common units and i-units outstanding (basic and diluted)
|
431
|
|
|
421
|
|
|
428
|
|
|
392
|
|
||||
Cash Distributions paid per limited partner unit
|
$
|
0.350
|
|
|
$
|
0.350
|
|
|
$
|
1.050
|
|
|
$
|
1.283
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Net income
|
$
|
207
|
|
|
$
|
196
|
|
|
$
|
566
|
|
|
$
|
550
|
|
Other comprehensive income, net of tax
|
|
|
|
|
|
|
|
||||||||
Change in cash flow hedges
|
—
|
|
|
(4
|
)
|
|
—
|
|
|
(25
|
)
|
||||
Reclassification to income on cash flow hedges
|
8
|
|
|
10
|
|
|
28
|
|
|
31
|
|
||||
Other comprehensive income, net of tax
|
8
|
|
|
6
|
|
|
28
|
|
|
6
|
|
||||
Comprehensive income
|
215
|
|
|
202
|
|
|
594
|
|
|
556
|
|
||||
Comprehensive income attributable to noncontrolling interests
|
(103
|
)
|
|
(103
|
)
|
|
(293
|
)
|
|
(262
|
)
|
||||
Series 1 Preferred unit distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
(29
|
)
|
||||
Accretion of discount on Series 1 Preferred units
|
—
|
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
||||
Comprehensive income attributable to common units and i-units
|
$
|
112
|
|
|
$
|
99
|
|
|
$
|
301
|
|
|
$
|
257
|
|
|
Nine months ended September 30,
|
||||||
|
2018
|
|
2017
|
||||
Operating activities:
|
|
|
|
|
|||
Income from continuing operations
|
$
|
566
|
|
|
$
|
607
|
|
Adjustments to reconcile net income to net cash provided by operating activities:
|
|
|
|
||||
Depreciation and amortization
|
330
|
|
|
329
|
|
||
Changes in unrealized loss on derivative instruments, net
|
8
|
|
|
1
|
|
||
Environmental costs, net of recoveries
|
(23
|
)
|
|
15
|
|
||
Distributions from equity investment in joint venture
|
93
|
|
|
28
|
|
||
Income from equity investment in joint venture
(Note 7)
|
(93
|
)
|
|
(28
|
)
|
||
Gain on sale of assets
(Note 6)
|
(22
|
)
|
|
(68
|
)
|
||
Allowance for equity used during construction
|
(48
|
)
|
|
(33
|
)
|
||
Amortization of debt issuance and hedging costs
|
27
|
|
|
27
|
|
||
Impairment of long-lived asset
(Note 6)
|
37
|
|
|
—
|
|
||
Other
|
1
|
|
|
—
|
|
||
Changes in operating assets and liabilities
|
62
|
|
|
(319
|
)
|
||
Net cash provided by operating activities
|
938
|
|
|
559
|
|
||
Net cash used in discontinued operations
|
—
|
|
|
(171
|
)
|
||
|
|
|
|
||||
Investing activities:
|
|
|
|
||||
Capital expenditures
|
(467
|
)
|
|
(418
|
)
|
||
Proceeds from the sale of assets
(Note 6)
|
15
|
|
|
319
|
|
||
Proceeds from the sale of Midcoast assets
(Note 6)
|
—
|
|
|
1,310
|
|
||
Equity investment in joint venture
|
(9
|
)
|
|
(1,577
|
)
|
||
Distributions from equity investment in joint venture in excess of cumulative earnings
|
57
|
|
|
12
|
|
||
Other
|
—
|
|
|
(3
|
)
|
||
Net cash used in investing activities
|
(404
|
)
|
|
(357
|
)
|
||
Net cash used in discontinued operations
|
—
|
|
|
(25
|
)
|
||
|
|
|
|
||||
Financing activities:
|
|
|
|
||||
Redemption of Series 1 Preferred units
(Note 11)
|
—
|
|
|
(1,200
|
)
|
||
Payment of Series 1 Preferred unit dividends
(Note 11)
|
—
|
|
|
(357
|
)
|
||
Net proceeds from Class A common unit issuances
(Note 11)
|
—
|
|
|
1,225
|
|
||
Distributions to partners
|
(390
|
)
|
|
(475
|
)
|
||
Repayments to General Partner and affiliates
|
(157
|
)
|
|
(1,706
|
)
|
||
Borrowings from General Partner and affiliates
|
297
|
|
|
1,500
|
|
||
Net borrowings (repayments) under credit facilities
(Note 8)
|
238
|
|
|
(1,065
|
)
|
||
Net commercial paper borrowings
(Note 8)
|
19
|
|
|
686
|
|
||
Repayment of long-term debt
(Note 8)
|
(400
|
)
|
|
—
|
|
||
Acquisition of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
(360
|
)
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
450
|
|
||
Contributions from noncontrolling interests
|
205
|
|
|
1,390
|
|
||
Distributions to noncontrolling interests
|
(364
|
)
|
|
(376
|
)
|
||
Other
|
(2
|
)
|
|
(1
|
)
|
||
Net cash used in financing activities
|
(554
|
)
|
|
(289
|
)
|
||
Net cash provided by discontinued operations
|
—
|
|
|
229
|
|
||
|
|
|
|
||||
Net decrease in cash and cash equivalents and restricted cash - continuing operations
|
(20
|
)
|
|
(87
|
)
|
||
Net increase in cash and cash equivalents and restricted cash - discontinued operations
|
—
|
|
|
33
|
|
||
Cash disposed as part of the Midcoast sale
|
—
|
|
|
(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
|
—
|
|
|
18
|
|
||
Cash and cash equivalents and restricted cash at end of period - continuing operations
|
$
|
15
|
|
|
$
|
28
|
|
Cash and cash equivalents and restricted cash at end of period - discontinued operations
|
$
|
—
|
|
|
$
|
—
|
|
|
September 30,
2018 |
|
December 31,
2017 |
||||
ASSETS
|
|
|
|
|
|
||
Current assets:
|
|
|
|
|
|||
Cash and cash equivalents
|
$
|
15
|
|
|
$
|
35
|
|
Receivables, trade and other
|
76
|
|
|
65
|
|
||
Due from General Partner and affiliates
|
84
|
|
|
101
|
|
||
Accrued receivables
|
87
|
|
|
105
|
|
||
Other current assets
|
24
|
|
|
24
|
|
||
|
286
|
|
|
330
|
|
||
Property, plant and equipment, net
|
13,104
|
|
|
12,896
|
|
||
Equity investment in joint venture
(Note 7)
|
1,517
|
|
|
1,565
|
|
||
Other assets, net
|
43
|
|
|
37
|
|
||
Total assets
|
$
|
14,950
|
|
|
$
|
14,828
|
|
LIABILITIES AND PARTNERS’ CAPITAL
|
|
|
|
||||
Current liabilities:
|
|
|
|
||||
Accounts payable and other
|
$
|
224
|
|
|
$
|
173
|
|
Due to General Partner and affiliates
|
34
|
|
|
48
|
|
||
Interest payable
|
88
|
|
|
85
|
|
||
Environmental liabilities
|
16
|
|
|
23
|
|
||
Property and other taxes payable
|
83
|
|
|
106
|
|
||
Current portion of long-term debt
|
600
|
|
|
500
|
|
||
|
1,045
|
|
|
935
|
|
||
Long-term debt
|
6,126
|
|
|
6,366
|
|
||
Loans from General Partner and affiliate
|
750
|
|
|
610
|
|
||
Other long-term liabilities
|
244
|
|
|
178
|
|
||
|
8,165
|
|
|
8,089
|
|
||
Commitments and contingencies
(Note 13)
|
|
|
|
|
|
||
Partners’ capital:
|
|
|
|
||||
Class E units (18.1 authorized and issued at September 30, 2018 and December 31, 2017, respectively)
|
774
|
|
|
774
|
|
||
Class A common units (326.5 outstanding at September 30, 2018 and December 31, 2017, respectively)
|
491
|
|
|
860
|
|
||
Class B common units (7.8 authorized and issued at September 30, 2018 and December 31, 2017, respectively)
|
—
|
|
|
—
|
|
||
i-units (98.6 and 89.8 authorized and issued at September 30, 2018 and December 31, 2017, respectively)
|
—
|
|
|
—
|
|
||
Class F units (1,000 authorized and issued at September 30, 2018 and December 31, 2017, respectively)
|
267
|
|
|
267
|
|
||
General Partner
|
321
|
|
|
68
|
|
||
Accumulated other comprehensive loss
|
(171
|
)
|
|
(199
|
)
|
||
Total Enbridge Energy Partners, L.P. partners’ capital
|
1,682
|
|
|
1,770
|
|
||
Noncontrolling interests
|
5,103
|
|
|
4,969
|
|
||
Total Partners’ capital
|
6,785
|
|
|
6,739
|
|
||
Total Liabilities and Partners’ capital
|
$
|
14,950
|
|
|
$
|
14,828
|
|
|
Nine months ended September 30,
|
||||||
|
2018
|
|
2017
|
||||
Series 1 Preferred units:
|
|
|
|
|
|
||
Beginning balance
|
$
|
—
|
|
|
$
|
1,192
|
|
Redemption of preferred units
(Note 11)
|
—
|
|
|
(1,200
|
)
|
||
Net income
|
—
|
|
|
29
|
|
||
Distribution payable
|
—
|
|
|
(29
|
)
|
||
Accretion of discount on preferred units
|
—
|
|
|
8
|
|
||
Ending balance
|
—
|
|
|
—
|
|
||
Class D units:
|
|
|
|
||||
Beginning balance
|
—
|
|
|
2,518
|
|
||
Waiver of Class D units
(Note 11)
|
—
|
|
|
(2,479
|
)
|
||
Distributions
|
—
|
|
|
(39
|
)
|
||
Ending balance
|
—
|
|
|
—
|
|
||
Class E units:
|
|
|
|
||||
Beginning balance
|
774
|
|
|
778
|
|
||
Net income
|
19
|
|
|
19
|
|
||
Distributions
|
(19
|
)
|
|
(23
|
)
|
||
Ending balance
|
774
|
|
|
774
|
|
||
Class A common units:
|
|
|
|
||||
Beginning balance
|
860
|
|
|
—
|
|
||
Net income
|
(26
|
)
|
|
141
|
|
||
Issuance of Class A units
(Note 11)
|
—
|
|
|
1,200
|
|
||
Distributions
|
(343
|
)
|
|
(381
|
)
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
29
|
|
||
Ending balance
|
491
|
|
|
989
|
|
||
Class B common units:
|
|
|
|
||||
Net income
|
8
|
|
|
9
|
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
1
|
|
||
Distributions
|
(8
|
)
|
|
(10
|
)
|
||
Ending balance
|
—
|
|
|
—
|
|
||
i-units:
|
|
|
|
||||
Net loss
|
—
|
|
|
(9
|
)
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
9
|
|
||
Ending balance
|
—
|
|
|
—
|
|
||
Class F units:
|
|
|
|
||||
Beginning balance
|
267
|
|
|
—
|
|
||
Issuance of Class F units
(Note 11)
|
—
|
|
|
263
|
|
||
Net income
|
11
|
|
|
11
|
|
||
Distributions
|
(11
|
)
|
|
(7
|
)
|
||
Ending balance
|
267
|
|
|
267
|
|
|
Nine months ended September 30,
|
||||||
|
2018
|
|
2017
|
||||
Incentive distribution units:
|
|
|
|
|
|
||
Beginning balance
|
—
|
|
|
495
|
|
||
Waiver of incentive distribution units
(Note 11)
|
—
|
|
|
(490
|
)
|
||
Distributions
|
—
|
|
|
(5
|
)
|
||
Ending balance
|
—
|
|
|
—
|
|
||
General Partner:
|
|
|
|
||||
Beginning balance
|
68
|
|
|
(667
|
)
|
||
Net income
|
261
|
|
|
80
|
|
||
Waiver of Class D units and incentive distribution units
(Note 11)
|
—
|
|
|
2,969
|
|
||
Issuance of Class F units
(Note 11)
|
—
|
|
|
(263
|
)
|
||
Contributions
|
—
|
|
|
92
|
|
||
Sale of Midcoast assets
(Note 6)
|
—
|
|
|
(2,127
|
)
|
||
Distributions
|
(8
|
)
|
|
(9
|
)
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
1
|
|
||
Ending balance
|
321
|
|
|
76
|
|
||
Accumulated other comprehensive loss:
|
|
|
|
||||
Beginning balance
|
(199
|
)
|
|
(339
|
)
|
||
Changes in fair value of derivative financial instruments recognized in other comprehensive income
|
—
|
|
|
(25
|
)
|
||
Changes in fair value of derivative financial instruments reclassified to income
|
28
|
|
|
31
|
|
||
Ending balance
|
(171
|
)
|
|
(333
|
)
|
||
Noncontrolling interests:
|
|
|
|
||||
Beginning balance
|
4,969
|
|
|
3,846
|
|
||
Capital contributions
|
205
|
|
|
1,410
|
|
||
Sale of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
411
|
|
||
Acquisition of noncontrolling interest in subsidiary
(Note 12)
|
—
|
|
|
(360
|
)
|
||
Sale of Midcoast assets
(Note 6)
|
—
|
|
|
(297
|
)
|
||
Net income
|
293
|
|
|
262
|
|
||
Distributions to noncontrolling interests
|
(364
|
)
|
|
(376
|
)
|
||
Ending balance
|
5,103
|
|
|
4,896
|
|
||
Total Partners’ Capital at end of period
|
$
|
6,785
|
|
|
$
|
6,669
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||
|
2018
|
|
2018
|
||||
|
(in millions)
|
||||||
Operating revenues:
|
|
|
|
||||
Transportation
|
$
|
543
|
|
|
$
|
1,633
|
|
Storage and other
|
21
|
|
|
70
|
|
||
Total revenues from contracts with customers
|
564
|
|
|
1,703
|
|
||
Other
|
(4
|
)
|
|
(14
|
)
|
||
Total revenues
|
$
|
560
|
|
|
$
|
1,689
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30, 2018
|
||||
|
2018
|
|
2018
|
||||
|
(in millions)
|
||||||
Revenues from products and services transferred over time - crude oil pipeline transportation and storage
|
$
|
564
|
|
|
$
|
1,703
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
|
(in millions, except per unit amounts)
|
||||||||||||||
Continuing operations:
|
|
|
|
|
|
|
|
|
|
|
|
||||
Net income
|
$
|
207
|
|
|
$
|
196
|
|
|
$
|
566
|
|
|
$
|
607
|
|
Noncontrolling interests
|
(103
|
)
|
|
(103
|
)
|
|
(293
|
)
|
|
(281
|
)
|
||||
Series 1 Preferred unit distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
(29
|
)
|
||||
Accretion of discount on Series 1 Preferred units
|
—
|
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
||||
Net income - continuing operations
|
104
|
|
|
93
|
|
|
273
|
|
|
289
|
|
||||
Distributions:
|
|
|
|
|
|
|
|
||||||||
Incentive distributions to Class F units
|
(4
|
)
|
|
(4
|
)
|
|
(11
|
)
|
|
(12
|
)
|
||||
Distributed earnings attributed to our General Partner
|
(3
|
)
|
|
(3
|
)
|
|
(10
|
)
|
|
(9
|
)
|
||||
Distributed earnings attributed to Class E units
|
(6
|
)
|
|
(6
|
)
|
|
(19
|
)
|
|
(19
|
)
|
||||
Total distributed earnings to our General Partner, Class E and Class F units
|
(13
|
)
|
|
(13
|
)
|
|
(40
|
)
|
|
(40
|
)
|
||||
Total distributed earnings attributed to our common units and i-units
|
(152
|
)
|
|
(148
|
)
|
|
(451
|
)
|
|
(441
|
)
|
||||
Total distributed earnings
|
(165
|
)
|
|
(161
|
)
|
|
(491
|
)
|
|
(481
|
)
|
||||
Overdistributed earnings
|
$
|
(61
|
)
|
|
$
|
(68
|
)
|
|
$
|
(218
|
)
|
|
$
|
(192
|
)
|
|
|
|
|
|
|
|
|
||||||||
Discontinued operations:
|
|
|
|
|
|
|
|
||||||||
Net loss
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(57
|
)
|
Noncontrolling interest
|
—
|
|
|
—
|
|
|
—
|
|
|
19
|
|
||||
Net loss - discontinued operations
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(38
|
)
|
Weighted average common units and i-units outstanding
|
431
|
|
|
421
|
|
|
428
|
|
|
392
|
|
||||
|
|
|
|
|
|
|
|
||||||||
Basic and diluted earnings per unit:
|
|
|
|
|
|
|
|
|
|
||||||
Distributed earnings per common unit and i-unit - continuing operations
(1)
|
$
|
0.35
|
|
|
$
|
0.35
|
|
|
$
|
1.05
|
|
|
$
|
1.13
|
|
Overdistributed earnings per common unit and i-unit
(2)
|
(0.14
|
)
|
|
(0.16
|
)
|
|
(0.50
|
)
|
|
(0.48
|
)
|
||||
Net income per common unit and i-unit (basic and diluted) - continuing operations
(3)
|
0.21
|
|
|
0.19
|
|
|
0.55
|
|
|
0.65
|
|
||||
Net loss per common unit and i-unit (basic and diluted) - discontinued operations
(3)
|
—
|
|
|
—
|
|
|
—
|
|
|
(0.10
|
)
|
||||
Net income per common unit and i-unit (basic and diluted)
|
$
|
0.21
|
|
|
$
|
0.19
|
|
|
$
|
0.55
|
|
|
$
|
0.55
|
|
(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 nine
months ended
September 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
September 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
nine
months ended
September 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.
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
|
(in millions)
|
||||||||||||||
Net regulatory (liability) asset balance at beginning of period
|
$
|
(34
|
)
|
|
$
|
(24
|
)
|
|
$
|
3
|
|
|
$
|
12
|
|
Prior period true-up
|
—
|
|
|
—
|
|
|
4
|
|
|
(5
|
)
|
||||
Current period (over) under recovery revenue adjustments
|
(13
|
)
|
|
29
|
|
|
(50
|
)
|
|
2
|
|
||||
Amortization of prior year regulatory asset
|
(2
|
)
|
|
(1
|
)
|
|
(6
|
)
|
|
(5
|
)
|
||||
Net regulatory (liability) asset balance at end of period
|
$
|
(49
|
)
|
|
$
|
4
|
|
|
$
|
(49
|
)
|
|
$
|
4
|
|
|
Nine months ended September 30,
|
||
|
2017
|
||
|
(in millions)
|
||
Operating revenues
|
$
|
1,161
|
|
Operating expenses:
|
|
||
Commodity costs
|
1,011
|
|
|
Operating and administrative
|
133
|
|
|
Depreciation and amortization
|
74
|
|
|
|
1,218
|
|
|
Operating loss
|
(57
|
)
|
|
Interest expense, net
|
17
|
|
|
Other income
|
18
|
|
|
Loss before income taxes
|
(56
|
)
|
|
Income tax expense
|
(1
|
)
|
|
Loss from discontinued operations, net of taxes
|
$
|
(57
|
)
|
|
Ownership
Interest
|
|
September 30,
2018 |
|
December 31,
2017 |
|
|
|
(in millions)
|
||
MarEn Bakken Company LLC
|
75%
|
|
$1,517
|
|
$1,565
|
|
Maturity
Dates
(1)
|
|
Total Facilities
(2)
|
|
Draws
(3)
|
|
Available
|
|
(in millions)
|
||||||
Enbridge Energy Partners, L.P.
|
2019 – 2022
|
|
$2,450
|
|
$1,710
|
|
$740
|
(1)
|
Includes
$185 million
of commitments that expire in 2020.
$175 million
of commitments expired on September 26, 2018.
|
(2)
|
Includes our
$1.8 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).
|
|
September 30,
|
||||||
|
2018
|
|
2017
|
||||
|
|
|
|
||||
|
(in millions)
|
||||||
Balance at beginning of year
|
$
|
106
|
|
|
$
|
98
|
|
Liabilities incurred
|
87
|
|
|
—
|
|
||
Accretion expense
|
4
|
|
|
5
|
|
||
Liabilities settled
|
(5
|
)
|
|
—
|
|
||
Revision in estimate
|
—
|
|
|
3
|
|
||
Balance at end of year
|
$
|
192
|
|
|
$
|
106
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
|
(in millions)
|
||||||||||||||
Eastern Access
|
$
|
27
|
|
|
$
|
37
|
|
|
$
|
88
|
|
|
$
|
114
|
|
U.S. Mainline Expansion
|
28
|
|
|
39
|
|
|
90
|
|
|
108
|
|
||||
North Dakota Pipeline Company
|
9
|
|
|
3
|
|
|
9
|
|
|
19
|
|
||||
U.S. Line 3 Replacement Program
|
11
|
|
|
8
|
|
|
36
|
|
|
19
|
|
||||
Enbridge Holdings (DakTex) L.L.C.
|
28
|
|
|
16
|
|
|
70
|
|
|
21
|
|
||||
Midcoast Energy Partners, L.P. - discontinued operations
|
—
|
|
|
—
|
|
|
—
|
|
|
(19
|
)
|
||||
Total
|
$
|
103
|
|
|
$
|
103
|
|
|
$
|
293
|
|
|
$
|
262
|
|
Distribution
Declaration Date
|
|
Distribution
Payment Date
|
|
Amount Paid to
EEP
|
|
Amount Paid to
noncontrolling Interest
|
|
Total DakTex
Distribution
|
||||||
|
|
|
|
(in millions)
|
||||||||||
September 27, 2018
|
|
September 27, 2018
|
|
$
|
13
|
|
|
$
|
41
|
|
|
$
|
54
|
|
June 28, 2018
|
|
June 28, 2018
|
|
$
|
11
|
|
|
$
|
35
|
|
|
$
|
46
|
|
April 6, 2018
|
|
April 6, 2018
|
|
12
|
|
|
38
|
|
|
50
|
|
|||
|
|
|
|
$
|
36
|
|
|
$
|
114
|
|
|
$
|
150
|
|
Distribution
Declaration Date
|
|
Distribution
Payment Date
|
|
Amount Paid to
EEP
|
|
Amount Paid to
noncontrolling Interest
|
|
Total Series EA
Distribution
|
||||||
|
|
|
|
(in millions)
|
||||||||||
July 25, 2018
|
|
August 14, 2018
|
|
$
|
26
|
|
|
$
|
38
|
|
|
$
|
64
|
|
April 27, 2018
|
|
May 15, 2018
|
|
32
|
|
|
47
|
|
|
79
|
|
|||
January 31, 2018
|
|
February 14, 2018
|
|
34
|
|
|
50
|
|
|
84
|
|
|||
|
|
|
|
$
|
92
|
|
|
$
|
135
|
|
|
$
|
227
|
|
Distribution
Declaration Date
|
|
Distribution
Payment Date
|
|
Amount Paid to
EEP
|
|
Amount Paid to
noncontrolling
Interest
|
|
Total Series ME
Distribution
|
||||||
|
|
|
|
(in millions)
|
||||||||||
July 25, 2018
|
|
August 14, 2018
|
|
$
|
11
|
|
|
$
|
31
|
|
|
$
|
42
|
|
April 27, 2018
|
|
May 15, 2018
|
|
13
|
|
|
40
|
|
|
53
|
|
|||
January 31, 2018
|
|
February 14, 2018
|
|
15
|
|
|
44
|
|
|
59
|
|
|||
|
|
|
|
$
|
39
|
|
|
$
|
115
|
|
|
$
|
154
|
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
|
(in millions)
|
||||||||||||||
Operating revenues
|
$
|
560
|
|
|
$
|
616
|
|
|
$
|
1,689
|
|
|
$
|
1,817
|
|
Operating expenses:
|
|
|
|
|
|
|
|
||||||||
Environmental costs, net of recoveries
|
4
|
|
|
1
|
|
|
(18
|
)
|
|
15
|
|
||||
Operating and administrative
|
62
|
|
|
77
|
|
|
198
|
|
|
239
|
|
||||
Operating and administrative - affiliates
|
64
|
|
|
85
|
|
|
195
|
|
|
235
|
|
||||
Power
|
83
|
|
|
81
|
|
|
235
|
|
|
221
|
|
||||
Depreciation and amortization
|
111
|
|
|
112
|
|
|
330
|
|
|
329
|
|
||||
Impairment of long-lived asset
|
1
|
|
|
—
|
|
|
37
|
|
|
—
|
|
||||
Gain on sale of assets
|
(22
|
)
|
|
(6
|
)
|
|
(22
|
)
|
|
(68
|
)
|
||||
|
303
|
|
|
350
|
|
|
955
|
|
|
971
|
|
||||
Operating income
|
257
|
|
|
266
|
|
|
734
|
|
|
846
|
|
||||
Interest expense, net
|
102
|
|
|
104
|
|
|
307
|
|
|
306
|
|
||||
Allowance for equity used during construction
|
16
|
|
|
12
|
|
|
48
|
|
|
33
|
|
||||
Income from equity investment in joint venture
|
37
|
|
|
22
|
|
|
93
|
|
|
28
|
|
||||
Other income (expense)
|
—
|
|
|
—
|
|
|
(1
|
)
|
|
5
|
|
||||
Income from continuing operations before income taxes
|
208
|
|
|
196
|
|
|
567
|
|
|
606
|
|
||||
Income tax benefit (expense)
|
(1
|
)
|
|
—
|
|
|
(1
|
)
|
|
1
|
|
||||
Income from continuing operations
|
207
|
|
|
196
|
|
|
566
|
|
|
607
|
|
||||
Loss from discontinued operations, net of taxes
|
—
|
|
|
—
|
|
|
—
|
|
|
(57
|
)
|
||||
Net income
|
207
|
|
|
196
|
|
|
566
|
|
|
550
|
|
||||
Noncontrolling interests
|
(103
|
)
|
|
(103
|
)
|
|
(293
|
)
|
|
(262
|
)
|
||||
Series 1 Preferred unit distributions
|
—
|
|
|
—
|
|
|
—
|
|
|
(29
|
)
|
||||
Accretion of discount on Series 1 Preferred units
|
—
|
|
|
—
|
|
|
—
|
|
|
(8
|
)
|
||||
Net income - controlling interests
|
$
|
104
|
|
|
$
|
93
|
|
|
$
|
273
|
|
|
$
|
251
|
|
•
|
Lower Lakehead System revenues driven by the regulatory impact of the U.S. Tax Reform and the change in FERC income tax policy which no longer permits recovery of an income tax allowance in cost of service rates.
|
•
|
An increase in operating revenue due to increased flow-through of recoverable power costs attributable to higher throughput and an increase in the index toll effective July 1, 2018.
|
•
|
Lower Lakehead System operating expenses driven by higher oil measurement gains and the timing of operating expenses; and
|
•
|
A higher gain on the disposition from the sale of unnecessary materials related to the Sandpiper Project.
|
•
|
Higher volumes on the Bakken Pipeline System resulting in higher earnings from our investment in the Bakken Pipeline System.
|
•
|
Lower Lakehead System revenues driven by the change in FERC income tax policy of approximately $65 million and the regulatory impact from the U.S. Tax Reform of approximately $60 million; and
|
•
|
Lower operating revenues from our Mid-Continent System as a result of the sale of the Ozark Pipeline in March 2017.
|
•
|
Higher operating revenue due to increased flow-through of recoverable power costs resulting from higher throughput on the Lakehead System; and
|
•
|
An increase in the Lakehead System index toll effective July 1, 2018.
|
•
|
An impairment charge of
$37 million
in 2018 related to our Line 10 crude oil pipeline, a component of the Lakehead System. The impairment charge results from the classification of Line 10 as held for sale and the subsequent measurement at the lower of carrying value and fair value less cost to sell; and
|
•
|
Higher flow-through power costs resulting from higher throughput on the Lakehead System.
|
•
|
Lower Lakehead System operating expenses driven by higher oil measurement gains and the timing of operating expenses;
|
•
|
A lower gain on disposition from the sale of unnecessary materials related to the Sandpiper Project; and
|
•
|
A reduction in net environmental accruals predominately attributable to Line 6B.
|
•
|
A full year of equity earnings from our interest in the Bakken Pipeline System, which was placed into service on June 1, 2017; and
|
•
|
Higher volumes on the Bakken Pipeline System resulting in higher earnings from our investment in the Bakken Pipeline System.
|
•
|
The sale of our interest in our Midcoast gas gathering and processing business resulting in the absence of losses attributable to NCI;
|
•
|
Equity earnings from our investment in the Bakken Pipeline System, which was placed into service on June 1, 2017, of which 75% of the earnings are attributable to NCI; and
|
•
|
The allocation of credits in relation to both the interest component and the cost of equity component of allowance for funds used during construction related to contributions made by our General Partner in relation to the U.S. L3R Program, of which 99% is attributable to NCI under the terms of our joint funding arrangement.
|
•
|
Lower income attributable to interests in Eastern Access and U.S. Mainline expansion, due to lower allocatable income as a result of the FERC income tax policy and U.S. Tax Reform.
|
|
Three months ended September 30,
|
|
Nine months ended September 30,
|
||||||||||||
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
|
(in millions)
|
||||||||||||||
Operating Results:
|
|
|
|
|
|
|
|
|
|
||||||
Operating revenues
|
$
|
560
|
|
|
$
|
616
|
|
|
$
|
1,689
|
|
|
$
|
1,817
|
|
Operating expenses:
|
|
|
|
|
|
|
|
||||||||
Environmental costs, net of recoveries
|
(4
|
)
|
|
(1
|
)
|
|
18
|
|
|
(15
|
)
|
||||
Operating and administrative
|
(125
|
)
|
|
(161
|
)
|
|
(383
|
)
|
|
(465
|
)
|
||||
Power
|
(83
|
)
|
|
(81
|
)
|
|
(235
|
)
|
|
(221
|
)
|
||||
Impairment of long-lived asset
|
(1
|
)
|
|
—
|
|
|
(37
|
)
|
|
—
|
|
||||
Gain on sale of assets
|
22
|
|
|
6
|
|
|
22
|
|
|
68
|
|
||||
Allowance for equity used during construction
|
16
|
|
|
12
|
|
|
48
|
|
|
33
|
|
||||
Income from equity investment in joint venture
|
37
|
|
|
22
|
|
|
93
|
|
|
28
|
|
||||
EBITDA
|
$
|
422
|
|
|
$
|
413
|
|
|
$
|
1,215
|
|
|
$
|
1,245
|
|
|
|
|
|
|
|
|
|
||||||||
Operating Statistics:
|
|
|
|
|
|
|
|
|
|
||||||
Lakehead System:
|
|
|
|
|
|
|
|
|
|
||||||
United States
(1)
|
2,073
|
|
|
1,982
|
|
|
2,109
|
|
|
2,008
|
|
||||
Canada
(1)
|
654
|
|
|
638
|
|
|
647
|
|
|
649
|
|
||||
Total Lakehead System delivery volumes
(1)
|
2,727
|
|
|
2,620
|
|
|
2,756
|
|
|
2,657
|
|
||||
Barrel miles (billions)
|
196
|
|
|
188
|
|
|
582
|
|
|
563
|
|
||||
Average haul (miles)
|
783
|
|
|
782
|
|
|
774
|
|
|
776
|
|
||||
Mid-Continent System delivery volumes
(1)
|
—
|
|
|
—
|
|
|
—
|
|
|
33
|
|
||||
Bakken Assets:
|
|
|
|
|
|
|
|
||||||||
North Dakota System to Clearbrook
(1)
|
220
|
|
|
219
|
|
|
218
|
|
|
214
|
|
||||
Bakken System to Cromer
(1)
|
58
|
|
|
84
|
|
|
56
|
|
|
116
|
|
||||
Total Bakken Assets delivery volumes
(1)
|
278
|
|
|
303
|
|
|
274
|
|
|
330
|
|
||||
Total Liquids segment delivery volumes
(1)
|
3,005
|
|
|
2,923
|
|
|
3,030
|
|
|
3,020
|
|
(1)
|
Average Bpd in thousands.
|
•
|
Higher volumes on the Bakken Pipeline System resulting in higher earnings from our investment in the Bakken Pipeline System;
|
•
|
An increase in the Lakehead System index toll effective July 1, 2018;
|
•
|
Lower operating expenses on the Lakehead System due to higher oil measurement gains and the timing of operating expenses; and
|
•
|
A higher gain on the disposition from the sale of unnecessary materials related to the Sandpiper Project.
|
•
|
Lower Lakehead System EBITDA driven by the regulatory impact of the U.S. Tax Reform and the FERC income tax policy to no longer permit recovery of an income tax allowance in cost of service rates.
|
•
|
Lower Lakehead System EBITDA driven by the change in FERC income tax policy which no longer permits recovery of an income tax allowance in cost of service rates and a lower tax rate pursuant to U.S. Tax Reform;
|
•
|
An impairment charge of $37 million in 2018 related to our Line 10 crude oil pipeline, a component of the Lakehead System, resulting from the classification as held for sale and the subsequent measurement at the lower of its carrying value or fair value less cost to sell;
|
•
|
Lower transportation revenues due to the sale of the Ozark Pipeline on March 1, 2017; and
|
•
|
A lower gain on disposition from the sale of unnecessary materials related to the Sandpiper Project.
|
•
|
Higher volumes on the Bakken Pipeline System resulting in higher earnings from our investment in the Bakken Pipeline System;
|
•
|
Lower operating expenses on our Lakehead System due to higher oil measurement gains and the timing of operating expenses; and
|
•
|
A reduction in net environmental accruals predominately attributable to Line 6B.
|
|
Ownership Interest
|
|
Estimated Capital
Costs
(1)
|
|
Expenditures to
Date
(2)
|
|
Status
|
|
Expected
In-Service Date
|
Lakehead System Mainline Expansion - Line 61
(3)(4)
|
25%
|
|
$0.4 billion
|
|
$0.4 billion
|
|
Substantially complete
|
|
2H - 2019
|
U.S. Line 3 Replacement Program
(5)
|
1%
|
|
$2.9 billion
|
|
$0.9 billion
|
|
Pre- construction
(6)
|
|
2H - 2019
|
(1)
|
These amounts are estimates and are subject to upward or downward adjustment based on various factors.
|
(2)
|
Expenditures to date reflect total cumulative expenditures incurred from inception of the project up to
September 30, 2018
.
|
(3)
|
Jointly funded 25% by us and 75% by our General Partner under the Mainline Expansion joint funding arrangement. Estimated capital costs are presented at 100% before our General Partner’s contributions.
|
(4)
|
Estimated in-service date will be adjusted to coincide with the in-service date of the U.S. L3R Program.
|
(5)
|
Jointly funded 1% by us and 99% by our General Partner under the Line 3 Replacement joint funding arrangement. Estimated capital costs are presented at 100% before our General Partner's contributions.
|
(6)
|
Construction of the Wisconsin portion of the project is complete as noted below. The remaining portion of the project is in pre-construction status.
|
•
|
U.S. L3R PROGRAM
- The Wisconsin portion of the U.S. L3R Program is in service. For additional updates on the project, refer to
Growth Projects – Regulatory Matters – U.S. L3R Program,
|
|
September 30, 2018
|
||
|
(in millions)
|
||
Cash and cash equivalents
|
$
|
15
|
|
Total capacity under the Credit Facilities
|
2,450
|
|
|
Total capacity under the EUS 364-day Credit Facility
|
750
|
|
|
Less: Amounts outstanding under the Credit Facilities
|
388
|
|
|
Amounts outstanding under the EUS 364-day Credit Facility
|
750
|
|
|
Principal amount of commercial paper outstanding
|
1,322
|
|
|
Letters of credit outstanding
|
4
|
|
|
Total
|
$
|
751
|
|
Distribution Declaration Date
|
|
Record Date
|
|
Distribution
Payment Date
|
|
Distribution
per Unit
|
|
Cash
Available for
Distribution
|
|
Amount of
Distribution
of i-units
to i-unit
Holders
|
|
Retained
from
General
Partner
(1)
|
|
Distribution
of Cash
|
||||||||||
|
|
|
|
|
|
|
|
(in millions, except per unit amounts)
|
||||||||||||||||
July 25, 2018
|
|
August 7, 2018
|
|
August 14, 2018
|
|
$
|
0.35
|
|
|
$
|
164
|
|
|
$
|
33
|
|
|
$
|
1
|
|
|
$
|
130
|
|
April 27, 2018
|
|
May 8, 2018
|
|
May 15, 2018
|
|
$
|
0.35
|
|
|
$
|
163
|
|
|
$
|
32
|
|
|
$
|
1
|
|
|
$
|
130
|
|
January 31, 2018
|
|
February 7, 2018
|
|
February 14, 2018
|
|
$
|
0.35
|
|
|
$
|
162
|
|
|
$
|
31
|
|
|
$
|
1
|
|
|
$
|
130
|
|
(1)
|
We retained an amount equal to 2% of the i-unit distribution from our General Partner to maintain its 2% general partner interest in us.
|
|
Nine months ended September 30,
|
||||||
|
2018
|
|
2017
|
||||
|
(in millions)
|
||||||
Total cash provided by (used in):
|
|
|
|
|
|
||
Operating activities
|
$
|
938
|
|
|
$
|
559
|
|
Investing activities
|
(404
|
)
|
|
(357
|
)
|
||
Financing activities
|
(554
|
)
|
|
(289
|
)
|
||
Net increase (decrease) in cash and cash equivalents and restricted cash
|
(20
|
)
|
|
(87
|
)
|
||
Cash and cash equivalents and restricted cash at beginning of year
|
35
|
|
|
115
|
|
||
Cash and cash equivalents and restricted cash at end of period
|
$
|
15
|
|
|
$
|
28
|
|
•
|
Repayments on long-term debt of
$400 million
;
|
•
|
Lower contributions from NCI of
$1.2 billion
as we received funds of $1.1 billion in the second quarter of 2017 from our General Partner, as a result of the finalization of the joint funding arrangement, which resulted in our investment in the Bakken Pipeline System to be 75% owned by our General Partner and 25% by us; and
|
•
|
The absence of cash inflows of
$450 million
received from the sale of our 99% interest in the U.S. L3R Project to our General Partner during the first quarter of 2017.
|
•
|
Net borrowings on sources of short-term financing of
$636 million
; and
|
•
|
Net borrowings of
$346 million
under the EUS 364-day Credit Facility;
|
•
|
The absence of cash used in the acquisition of an additional 15% interest in the Eastern Access Projects of
$360 million
during the first half of 2017;
|
•
|
The absence of cash used in the payment on Series 1 Preferred unit dividends of
$357 million
during the first half of 2017; and
|
•
|
Decrease in distribution to partners of
$85 million
due to a reduction in our quarterly distribution from $0.583 per unit to $0.35 per unit in the first quarter of 2017.
|
•
|
the parties may be liable for expenses to one another under the terms and conditions of the Merger Agreement; and
|
•
|
there may be negative reactions from the financial markets due to the fact that current prices of our Class A common units may reflect a market assumption that the Proposed Merger will be completed.
|
•
|
changes in Enbridge's or our business, operations and prospects;
|
•
|
changes in market assessments of Enbridge's or our business, operations and prospects;
|
•
|
changes in market assessments of the likelihood that the Proposed Merger will be completed;
|
•
|
interest rates, commodity prices, general market, industry and economic conditions and other factors generally affecting the price of Enbridge common shares or our common units; and
|
•
|
federal, state and local legislation, governmental regulation and legal developments in the businesses in which Enbridge and we operate.
|
Exhibit Number
|
|
Description
|
|
||
|
||
|
||
|
||
|
||
|
||
101.INS*
|
|
XBRL Instance Document.
|
101.SCH*
|
|
XBRL Taxonomy Extension Schema Document.
|
101.CAL*
|
|
XBRL Taxonomy Extension Calculation Linkbase Document.
|
101.DEF*
|
|
XBRL Taxonomy Extension Definition Linkbase Document.
|
101.LAB*
|
|
XBRL Taxonomy Extension Label Linkbase Document.
|
101.PRE*
|
|
XBRL Taxonomy Extension Presentation Linkbase Document.
|
|
Enbridge Energy Partners, L.P.
(Registrant)
|
|
|
|
|
|
By:
|
Enbridge Energy Management, L.L.C.
as delegate of the General Partner
|
|
|
|
Date: November 1, 2018
|
By:
|
/s/ Mark A. Maki
|
|
|
Mark A. Maki
President
(Principal Executive Officer)
|
|
|
|
Date: November 1, 2018
|
By:
|
/s/ Christopher J. Johnston
|
|
|
Christopher J. Johnston
Vice President, Finance
(Principal Financial Officer)
|
1 Year Enbridge Energy Chart |
1 Month Enbridge Energy Chart |
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