EnLink Midstream (ENLC) 10-Q 3 May 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	Apr. 27, 2017
Entity Information [Abstract]
Document Type	10-Q
Document Fiscal Period Focus	Q1
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2,017
Amendment Flag	false
Entity Registrant Name	Enlink Midstream, LLC
Entity Central Index Key	1,592,000
Entity Current Reporting Status	Yes
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		180,557,694

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 15	$ 11.7
Accounts receivable:
Trade, net of allowance for bad debt of $0.1 and $0.1, respectively	47.1	63.9
Accrued revenue and other	358.1	369.6
Related party	107.1	100.2
Fair value of derivative assets	2.1	1.3
Natural gas and NGLs inventory, prepaid expenses and other	28.1	33.5
Investment in unconsolidated affiliates—current	0	193.1
Total current assets	557.5	773.3
Property and equipment, net of accumulated depreciation of $2,220.6 and $2,124.1, respectively	6,396.3	6,256.7
Fair value of derivative assets	0.1	0
Intangible assets, net of accumulated amortization of $201.1 and $171.6, respectively	1,594.7	1,624.2
Goodwill	1,542.2	1,542.2
Investment in unconsolidated affiliates—non-current	84.5	77.3
Other assets, net	2.2	2.2
Total assets	10,177.5	10,275.9
Current liabilities:
Accounts payable and drafts payable	70.9	69.2
Accounts payable to related party	12.5	10.4
Accrued gas, NGLs, condensate and crude oil purchases	306.2	333.3
Fair value of derivative liabilities	2.9	7.6
Installment payable, net of discount of $19.9 and $0.5, respectively	230.1	249.5
Other current liabilities	214.3	217.5
Total current liabilities	836.9	887.5
Long-term debt	3,521.1	3,295.3
Asset retirement obligations	13.7	13.5
Other long-term liabilities	42.1	42.5
Installment payable, net of discount of $26.3 at December 31, 2016	0	223.7
Deferred tax liability	544.5	542.6
Fair value of derivative liabilities	0.3	0
Redeemable non-controlling interest	4.8	5.2
Members’ equity:
Members’ equity (180,551,299 and 180,049,316 units issued and outstanding at March 31, 2017 and December 31, 2016, respectively)	1,836.7	1,880.9
Non-controlling interest	3,377.4	3,384.7
Total members’ equity	5,214.1	5,265.6
Commitments and contingencies (Note 15)
Total liabilities and members’ equity	$ 10,177.5	$ 10,275.9

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
ASSETS
Allowance for bad debt	$ 0.1	$ 0.1
Property and equipment, accumulated depreciation	2,220.6	2,124.1
Intangible assets, accumulated amortization	201.1	171.6
Liabilities:
Current installment payable discount	19.9	0.5
Noncurrent installment payable discount	$ 0	$ 26.3
Members’ equity:
Common units issued (in shares)	180,551,299	180,049,316
Common units outstanding (in shares)	180,551,299	180,049,316

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
Revenues:
Product sales		$ 990	$ 588.5
Product sales—related parties		42.7	24.5
Midstream services		127.4	114.5
Midstream services—related parties		159	162.6
Gain (loss) on derivative activity		2.8	(0.4)
Total revenues		1,321.9	889.7
Operating costs and expenses:
Cost of sales	[1]	1,002.3	586.2
Operating expenses	[2]	104.1	98.2
General and administrative		36.1	35.1
(Gain) loss on disposition of assets		5.1	(0.2)
Depreciation and amortization		128.3	121.9
Impairments		7	873.3
Gain on litigation settlement		(17.5)	0
Total operating costs and expenses		1,265.4	1,714.5
Operating income (loss)		56.5	(824.8)
Other income (expense):
Interest expense, net of interest income		(44.9)	(44)
Income (loss) from unconsolidated affiliates		0.7	(2.4)
Other income		0	0.1
Total other expense		(44.2)	(46.3)
Income (loss) before non-controlling interest and income taxes		12.3	(871.1)
Income tax provision		(3)	(0.2)
Net income (loss)		9.3	(871.3)
Net income (loss) attributable to the non-controlling interest		11.2	(413.7)
Net loss attributable to EnLink Midstream, LLC		$ (1.9)	$ (457.6)
Net loss attributable to EnLink Midstream, LLC per unit:
Basic common unit (in dollars per share)		$ (0.01)	$ (2.56)
Diluted common unit (in dollars per share)		$ (0.01)	$ (2.56)
[1]	Includes related party cost of sales of $28.7 million and $42.6 million for the three months ended March 31, 2017 and 2016, respectively.
[2]	Includes related party operating expenses of $0.2 million and $0.1 million for the three months ended March 31, 2017 and 2016, respectively.

Consolidated Statements of Ope5

Consolidated Statements of Operations (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Statement [Abstract]
Related party cost of sales	$ 28.7	$ 42.6
Related party operating expenses	$ 0.2	$ 0.1

Consolidated Statement of Chang

Consolidated Statement of Changes in Members' Equity - 3 months ended Mar. 31, 2017 - USD ($) $ in Millions	Total	Redeemable Non-Controlling Interest (Temporary Equity)	Common Units	Non-Controlling Interest
Member equity, beginning balance at Dec. 31, 2016	$ 5,265.6		$ 1,880.9	$ 3,384.7
Units outstanding, beginning balance (in shares) at Dec. 31, 2016	180,049,316		180,000,000
Redeemable noncontrolling interest, beginning balance at Dec. 31, 2016		$ 5.2
Increase (Decrease) in Members' Equity
Issuance of common units by ENLK	$ 55.2			55.2
Conversion of restricted units for common units, net of units withheld for taxes	(4.3)		$ (4.3)
Conversion of restricted units for common units, net of units withheld for taxes (in shares)			600,000
Non-controlling partner’s impact of conversion of restricted units	(5)			(5)
Unit-based compensation	18		$ 9	9
Change in equity due to issuance of units by ENLK	0.3		(0.6)	0.9
Non-controlling interest distributions	(100.7)	(0.4)		(100.7)
Non-controlling interest contribution	20.8			20.8
Distributions to members	(46.4)		(46.4)
Distributions to redeemable non-controlling interest	(100.7)	(0.4)		(100.7)
Contribution from Devon to ENLK	1.3			1.3
Net income (loss)	9.3		(1.9)	11.2
Member equity, end balance at Mar. 31, 2017	$ 5,214.1		$ 1,836.7	$ 3,377.4
Units outstanding, end balance (in shares) at Mar. 31, 2017	180,551,299		180,600,000
Redeemable noncontrolling interest, ending balance at Mar. 31, 2017		$ 4.8

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities:
Net income (loss)	$ 9.3	$ (871.3)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Impairments	7	873.3
Depreciation and amortization	128.3	121.9
(Gain) loss on disposition of assets	5.1	(0.2)
Non-cash unit-based compensation	19.4	8
(Gain) loss on derivatives recognized in net income (loss)	(2.8)	0.4
Cash settlements on derivatives	(2.9)	5.6
Amortization of debt issue costs	1	0.9
Amortization of net discount on notes	6.3	11.7
Redeemable non-controlling interest expense	0	0.2
(Income) loss from unconsolidated affiliates	(0.7)	2.4
Other	2.5	(0.7)
Changes in assets and liabilities, net of assets acquired and liabilities assumed:
Accounts receivable, accrued revenue and other	21.5	32
Natural gas and NGLs inventory, prepaid expenses and other	2.4	22.4
Accounts payable, accrued gas and crude oil purchases and other accrued liabilities	(18.8)	(12.2)
Net cash provided by operating activities	177.6	194.4
Cash flows from investing activities, net of assets acquired and liabilities assumed:
Additions to property and equipment	(256.3)	(135.4)
Acquisition of business, net of cash acquired	0	(796.8)
Proceeds from sale of unconsolidated affiliate investment	189.7	0.2
Proceeds from sale of property	0.5	0
Investment in unconsolidated affiliates	(6)	(7.1)
Distribution from unconsolidated affiliates in excess of earnings	2.8	6.2
Net cash used in investing activities	(69.3)	(932.9)
Cash flows from financing activities:
Proceeds from borrowings	813	397.3
Payments on borrowings	(587.3)	(259)
Payment of installment payable for EnLink Oklahoma T.O. acquisition	(250)	0
Payments on capital lease obligations	(1)	(1.1)
Debt financing costs	(0.2)	(0.3)
Conversion of restricted units, net of units withheld for taxes	(4.3)	(1.1)
Conversion of ENLK restricted units, net of units withheld for taxes	(5)	(1.1)
Proceeds from issuance of ENLK common units	55.2	2.1
Distributions to non-controlling partners	(101.1)	(93.1)
Distribution to members	(46.4)	(46.3)
Contribution from Devon	1.3	1.4
Proceeds from issuance of ENLK Preferred Units	0	724.5
Contributions by non-controlling partners	20.8	3
Net cash provided by (used in) financing activities	(105)	726.3
Net increase (decrease) in cash and cash equivalents	3.3	(12.2)
Cash and cash equivalents, beginning of period	11.7	18
Cash and cash equivalents, end of period	15	5.8
Cash paid for interest	15.9	3.5
Cash paid (refund) for income taxes	$ 2.2	$ (6.6)

General

General	3 Months Ended
	Mar. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	ENLINK MIDSTREAM, LLC Notes to Consolidated Financial Statements March 31, 2017 (Unaudited) (1) General In this report, the terms “Company” or “Registrant” as well as the terms “ENLC,” “our,” “we,” and “us,” or like terms, are sometimes used as abbreviated references to EnLink Midstream, LLC and its consolidated subsidiaries. References in this report to “EnLink Midstream Partners, LP,” the “Partnership,” “ENLK” or like terms refer to EnLink Midstream Partners, LP itself or EnLink Midstream Partners, LP together with its consolidated subsidiaries, including EnLink Midstream Operating, LP and EnLink Oklahoma Gas Processing, LP (“EnLink Oklahoma T.O.”). EnLink Oklahoma T.O. is sometimes used to refer to EnLink Oklahoma Gas Processing, LP itself or EnLink Oklahoma Gas Processing, LP together with its consolidated subsidiaries. (a) Organization of Business EnLink Midstream, LLC is a Delaware limited liability company formed in October 2013. The Company’s common units are traded on the New York Stock Exchange under the symbol “ENLC.” Our assets consist of equity interests in EnLink Midstream Partners, LP and EnLink Oklahoma T.O. ENLK is a publicly traded limited partnership engaged in the gathering, transmission, processing and marketing of natural gas and natural gas liquids (“NGLs”), condensate and crude oil, as well as providing crude oil, condensate and brine services to producers. EnLink Oklahoma T.O. is a partnership held by us and ENLK, and is engaged in the gathering and processing of natural gas. As of March 31, 2017 , our interests in ENLK and EnLink Oklahoma T.O. consist of the following: • 88,528,451 common units representing an aggregate 22.0% limited partner interest in ENLK; • 100.0% ownership interest in EnLink Midstream Partners GP, LLC, the general partner of ENLK (the “General Partner”), which owns a 0.4% general partner interest and all of the incentive distribution rights in ENLK; and • 16% limited partner interest in EnLink Oklahoma T.O. (b) Nature of Business We primarily focus on providing midstream energy services, including gathering, transmission, processing, fractionation, storage, condensate stabilization, brine services and marketing to producers of natural gas, natural gas liquids (“NGLs”) , crude oil and condensate. We connect the wells of producers in our market areas to our gathering systems, process natural gas to remove NGLs, fractionate NGLs into purity products and market those products for a fee, transport natural gas and ultimately provide natural gas to a variety of markets. We purchase natural gas from natural gas producers and other supply sources and sell that natural gas to utilities, industrial consumers, other marketers and pipelines. We operate processing plants that process gas transported to the plants by major interstate pipelines or from our own gathering systems mainly under a variety of fee-based arrangements. We provide a variety of crude oil and condensate services, which include crude oil and condensate gathering and transmission via pipelines, barges, rail and trucks, condensate stabilization and brine disposal. We also have crude oil and condensate terminal facilities that provide access for crude oil and condensate producers to premium markets. Our gas gathering systems consist of networks of pipelines that collect natural gas from points near producing wells and transport it to larger pipelines for further transmission. Our transmission pipelines primarily receive natural gas from our gathering systems and from third party gathering and transmission systems and deliver natural gas to industrial end-users, utilities and other pipelines. We also have transmission lines that transport NGLs from east Texas and from our south Louisiana processing plants to our fractionators in south Louisiana. Our crude oil and condensate gathering and transmission systems consist of trucking facilities, pipelines, rail and barge facilities that, in exchange for a fee, transport crude oil from a producer site to end users and other pipelines. Our processing plants remove NGLs and CO2 from a natural gas stream, and our fractionators separate the NGLs into separate NGL products, including ethane, propane, iso-butane, normal butane and natural gasoline.

Significant Accounting Policies

Significant Accounting Policies	3 Months Ended
	Mar. 31, 2017
Accounting Policies [Abstract]
Significant Accounting Policies	(2) Significant Accounting Policies (a) Basis of Presentation The accompanying consolidated financial statements are prepared in accordance with the instructions to Form 10-Q, are unaudited and do not include all the information and disclosures required by generally accepted accounting principles in the United States of America (“GAAP”) for complete financial statements. All adjustments that, in the opinion of management, are necessary for a fair presentation of the results of operations for the interim periods have been made and are of a recurring nature unless otherwise disclosed herein. The results of operations for such interim periods are not necessarily indicative of results of operations for a full year. All significant intercompany balances and transactions have been eliminated in consolidation. (b) Adopted Accounting Standards In March 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”), which simplifies several aspects related to the accounting for share-based payment transactions. Effective January 1, 2017, we adopted ASU 2016-09. We prospectively adopted the guidance that requires excess tax benefits and deficiencies be recognized on the income statement. The new cash flow statement guidance requires the presentation of excess tax benefits and deficiencies as an operating activity and the presentation of cash paid by an employer when directly withholding shares for tax-withholding purposes as a financing activity, and this treatment is consistent with our historical accounting treatment. Finally, we elected to estimate the number of awards that are expected to vest, which is consistent with our historical accounting treatment. The adoption of the new guidance did not materially affect the consolidated statement of operations for the three months ended March 31, 2017 . In January 2017, the FASB issued ASU 2017-04, Intangibles — Goodwill and Other (Topic 350) — Simplifying the Test for Goodwill Impairment (“ASU 2017-04”). ASU 2017-04 simplifies the accounting for goodwill impairments by eliminating the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test referenced in Accounting Standards Codification (“ASC”) 350, Intangibles - Goodwill and Other (“ASC 350”). As a result, an entity should perform its annual, or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit’s fair value. However, the impairment loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including any interim impairment tests within those annual periods, with early application permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. In January 2017, we elected to early adopt ASU 2017-04, and the adoption had no impact on our consolidated financial statements. We will perform future goodwill impairment tests according to ASU 2017-04. (c) Accounting Standards to be Adopted in Future Periods In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) — Amendments to the FASB Accounting Standards Codification (“ASU 2016-02”). Lessees will need to recognize virtually all of their leases on the balance sheet by recording a right-of-use asset and lease liability. Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model and the new revenue recognition standard. Existing sale-leaseback guidance is replaced with a new model applicable to both lessees and lessors. Additional revisions have been made to embedded leases, reassessment requirements and lease term assessments including variable lease payment, discount rate and lease incentives. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018 including interim periods within those annual periods. Early adoption is permitted. Entities are required to adopt ASU 2016-02 using a modified retrospective transition. We are currently assessing the impact of adopting ASU 2016-02. This assessment includes the gathering and evaluation of our current lease contracts and the analysis of contracts that may contain lease components. While we cannot currently estimate the quantitative effect that ASU 2016-02 will have on our consolidated financial statements, the adoption of ASU 2016-02 will increase our asset and liability balances on the consolidated balance sheets due to the required recognition of right-of-use assets and corresponding lease liabilities for all lease obligations that are currently classified as operating leases. In addition, there are industry-specific concerns with the implementation of ASU 2016-02, including the application of ASU 2016-02 to contracts involving easements/right-of-ways, which will require further evaluation before we are able to fully assess the impact on our consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”), which established ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”). ASC 606 will replace existing revenue recognition requirements in GAAP and will require entities to recognize revenue at an amount that reflects the consideration to which we expect to be entitled in exchange for transferring goods or services to a customer. ASC 606 will also require significantly expanded disclosures regarding the qualitative and quantitative information of our nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients (“ASU 2016-12”), which updated ASU 2014-09. ASU 2016-12 clarifies certain core recognition principles, including collectability, sales tax presentation, noncash consideration, contract modifications and completed contracts at transition and disclosures no longer required if the full retrospective transition method is adopted. ASU 2014-09 and ASU 2016-12 are effective for annual reporting periods beginning after December 15, 2017, including interim periods within those annual periods, and are to be applied using the modified retrospective or full retrospective transition methods, with early application permitted for annual reporting periods beginning after December 15, 2016. We plan to use the modified retrospective transition method and do not plan to early adopt ASC 606. We have aggregated and reviewed our contracts that are within the scope of ASC 606. Based on our evaluation to date, we do not anticipate this standard will have a material impact on our consolidated financial statements. We continue to evaluate the impacts ASC 606 will have on our disclosures. (d) Property, Plant & Equipment Gain or Loss on Disposition. We recognize any gain or loss upon the disposition or retirement of property, plant and equipment in operating income in the consolidated statement of operations. For the three months ended March 31, 2017 , we retired certain plant assets in the Permian Basin that were damaged by fire, which resulted in a loss on disposition of $5.1 million . Impairment Review. We evaluate our property, plant and equipment for potential impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. The carrying amount of a long-lived asset is not recoverable when it exceeds the undiscounted sum of the future cash flows expected to result from the use and eventual disposition of the asset. Estimates of expected future cash flows represent management’s best estimate based on reasonable and supportable assumptions. When the carrying amount of a long-lived asset is not recoverable, an impairment loss is recognized equal to the excess of the asset’s carrying value over its fair value. For the three months ended March 31, 2017 , we recognized an impairment of $7.0 million , which related to the carrying values of right-of-ways that expired and a brine disposal well that will be abandoned.

Acquisitions

Acquisitions	3 Months Ended
	Mar. 31, 2017
Business Combinations [Abstract]
Acquisitions	(3) Acquisition On January 7, 2016 , ENLC and ENLK acquired a 16% and 84% voting interest, respectively, in EnLink Oklahoma T.O. for approximately $1.4 billion . The first installment of $1.02 billion for the acquisition was paid at closing. The second installment of $250.0 million was paid on January 6, 2017, and the final installment of $250.0 million is due no later than January 7, 2018. ENLK’s installment payables are valued net of discount within the total purchase price. The first installment of approximately $1.02 billion was funded by (a) approximately $783.6 million in cash paid by ENLK, which was primarily derived from the issuance of Series B Cumulative Convertible Preferred Units (“Preferred Units”), (b) 15,564,009 common units representing limited liability company interests in ENLC issued directly by ENLC and (c) approximately $22.2 million in cash paid by ENLC. The transaction was accounted for using the acquisition method. The following table presents the consideration ENLC and ENLK paid and the fair value of the identified assets received and liabilities assumed at the acquisition date (in millions): Consideration: Cash $ 805.8 Issuance of common units 214.9 ENLK’s total installment payable, net of discount of $79.1 million assuming payments made on January 7, 2017 and 2018 420.9 Total consideration $ 1,441.6 Purchase Price Allocation: Assets acquired: Current assets (including $12.8 million in cash) $ 23.0 Property, plant and equipment 406.1 Intangibles 1,051.3 Liabilities assumed: Current liabilities (38.8 ) Total identifiable net assets $ 1,441.6 The fair value of assets acquired and liabilities assumed are based on inputs that are not observable in the market and thus represent Level 3 inputs. We recognized intangible assets related to customer relationships and determined their fair value using the income approach. The acquired intangible assets are amortized on a straight-line basis over the estimated customer life of approximately 15 years . We incurred a total of $4.8 million of direct transaction costs, of which $4.3 million were recognized as expense for the three months ended March 31, 2016 . These costs are included in general and administrative costs in the accompanying consolidated statements of operations. For the period from January 7, 2016 to March 31, 2016 , we recognized $27.3 million of revenues and $14.2 million of net loss related to the assets acquired.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	(4) Goodwill and Intangible Assets Goodwill Goodwill is the cost of an acquisition less the fair value of the net identifiable assets of the acquired business. The fair value of goodwill is based on inputs that are not observable in the market and thus represent Level 3 inputs. We evaluate goodwill for impairment annually as of October 31, and whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. We perform our goodwill assessments at the reporting unit level for all reporting units. We use a discounted cash flow analysis to perform the assessments. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples and estimated future cash flows including volume and price forecasts and estimated operating and general and administrative costs. In estimating cash flows, we incorporate current and historical market and financial information, among other factors. Impairment determinations involve significant assumptions and judgments and differing assumptions regarding any of these inputs could have a significant effect on the various valuations. If actual results are not consistent with our assumptions and estimates, or our assumptions and estimates change due to new information, we may be exposed to goodwill impairment charges, which would be recognized in the period in which the carrying value exceeds fair value. During February 2016, we determined that weakness in the overall energy sector, driven by low commodity prices, together with a decline in our unit price, caused a change in circumstances warranting an interim impairment test. Based on these triggering events, we performed a goodwill impairment analysis in the first quarter of 2016 on all reporting units. Based on this analysis, a goodwill impairment loss for the Texas, Crude and Condensate, and Corporate reporting units in the amount of $873.3 million was recognized in the first quarter of 2016 and is included as an impairment loss in the consolidated statement of operations for the three months ended March 31, 2016 . We concluded that the fair value of our Oklahoma reporting unit exceeded its carrying value, and the amount of goodwill disclosed on the consolidated balance sheet associated with this reporting unit is recoverable. Therefore, no other goodwill impairment was identified or recorded for this reporting unit as a result of our goodwill impairment analysis. During the first quarter of 2017, we elected to early adopt ASU 2017-04, which simplifies the accounting for goodwill impairments by eliminating the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test referenced in ASC 350. Although no interim assessment was required for the first quarter of 2017, we will perform future goodwill impairment tests according to ASU 2017-04. For additional information, see Note 2—Significant Accounting Policies . Intangible Assets Intangible assets associated with customer relationships are amortized on a straight-line basis over the expected period of benefits of the customer relationships, which range from 10 to 20 years. The following table represents our change in carrying value of intangible assets (in millions): Gross Carrying Amount Accumulated Amortization Net Carrying Amount Three Months Ended March 31, 2017 Customer relationships, beginning of period $ 1,795.8 $ (171.6 ) $ 1,624.2 Amortization expense — (29.5 ) (29.5 ) Customer relationships, end of period $ 1,795.8 $ (201.1 ) $ 1,594.7 The weighted average amortization period is 13.7 years . Amortization expense was approximately $29.5 million and $27.5 million for the three months ended March 31, 2017 and 2016 , respectively. The following table summarizes our estimated aggregate amortization expense for the next five years (in millions): 2017 (remaining) $ 88.4 2018 117.9 2019 117.9 2020 117.9 2021 117.9 Thereafter 1,034.7 Total $ 1,594.7

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions	(5) Related Party Transactions We engage in various transactions with Devon and other related parties. For the three months ended March 31, 2017 and 2016 , Devon accounted for 14.9% and 21.0% of our revenues, respectively. We had an accounts receivable balance related to transactions with Devon of $106.9 million as of March 31, 2017 and $100.2 million as of December 31, 2016 . Additionally, we had an accounts payable balance related to transactions with Devon of $11.8 million as of March 31, 2017 and $10.4 million as of December 31, 2016 . Management believes these transactions are executed on terms that are fair and reasonable and are consistent with terms for transactions with unrelated third parties. The amounts related to related party transactions are specified in the accompanying financial statements.

Long-Term Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Long-Term Debt	(6) Long-Term Debt As of March 31, 2017 and December 31, 2016 , long-term debt consisted of the following (in millions): March 31, 2017 December 31, 2016 Outstanding Principal Premium (Discount) Long-Term Debt Outstanding Principal Premium (Discount) Long-Term Debt ENLK credit facility due 2020 (1) $ 330.0 $ — $ 330.0 $ 120.0 $ — $ 120.0 ENLC credit facility due 2019 (2) 43.5 — 43.5 27.8 — 27.8 2.70% Senior unsecured notes due 2019 400.0 (0.2 ) 399.8 400.0 (0.3 ) 399.7 7.125% Senior unsecured notes due 2022 (3) 162.5 15.2 177.7 162.5 16.0 178.5 4.40% Senior unsecured notes due 2024 550.0 2.4 552.4 550.0 2.5 552.5 4.15% Senior unsecured notes due 2025 750.0 (1.1 ) 748.9 750.0 (1.1 ) 748.9 4.85% Senior unsecured notes due 2026 500.0 (0.6 ) 499.4 500.0 (0.7 ) 499.3 5.60% Senior unsecured notes due 2044 350.0 (0.2 ) 349.8 350.0 (0.2 ) 349.8 5.05% Senior unsecured notes due 2045 450.0 (6.6 ) 443.4 450.0 (6.6 ) 443.4 Debt classified as long-term $ 3,536.0 $ 8.9 $ 3,544.9 $ 3,310.3 $ 9.6 $ 3,319.9 Debt issuance cost (4) (23.8 ) (24.6 ) Long-term debt, net of unamortized issuance cost $ 3,521.1 $ 3,295.3 (1) Bears interest based on Prime and/or LIBOR plus an applicable margin. The effective interest rate was 3.0% and 2.3% at March 31, 2017 and December 31, 2016 , respectively. (2) Bears interest based on Prime and/or LIBOR plus an applicable margin. The effective interest rate was 3.1% and 3.4% at March 31, 2017 and December 31, 2016 , respectively. (3) On April 3, 2017, ENLK issued notice to redeem its 7.125% senior unsecured notes due 2022 (the “2022 notes”). The 2022 notes will be redeemed on June 1, 2017 at 103.6% of the principal amount, plus accrued unpaid interest, for aggregate cash consideration of $174.1 million . (4) Net of amortization of $10.0 million and $9.0 million at March 31, 2017 and December 31, 2016 , respectively. ENLC Credit Facility We have a $250.0 million revolving credit facility that matures on March 7, 2019 and includes a $125.0 million letter of credit subfacility (the “ENLC Credit Facility”). Our obligations under the ENLC Credit Facility are guaranteed by two of our wholly-owned subsidiaries and secured by first priority liens on (i) 88,528,451 ENLK common units and the 100% membership interest in the General Partner indirectly held by us, (ii) the 100% equity interest in each of our wholly-owned subsidiaries held by us and (iii) any additional equity interests subsequently pledged as collateral under the ENLC Credit Facility. The ENLC Credit Facility contains certain financial, operational and legal covenants. The financial covenants are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter, and include (i) maintaining a maximum consolidated leverage ratio (as defined in the ENLC Credit Facility, but generally computed as the ratio of consolidated funded indebtedness to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) of 4.00 to 1.00, provided that the maximum consolidated leverage ratio is 4.50 to 1.00 during an acquisition period (as defined in the ENLC Credit Facility) and (ii) maintaining a minimum consolidated interest coverage ratio (as defined in the ENLC Credit Facility, but generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest charges) of 2.50 to 1.00 unless an investment grade event (as defined in the ENLC Credit Facility) occurs. Borrowings under the ENLC Credit Facility bear interest at our option at the Eurodollar Rate (the LIBOR Rate) plus an applicable margin (ranging from 1.75% to 2.50% ) or the Base Rate (the highest of the Federal Funds Rate plus 0.5% , the 30-day Eurodollar Rate plus 1.0% or the administrative agent’s prime rate) plus an applicable margin (ranging from 0.75% to 1.50% ). The applicable margins vary depending on our leverage ratio. Upon breach by us of certain covenants governing the ENLC Credit Facility, amounts outstanding under the ENLC Credit Facility, if any, may become due and payable immediately and the liens securing the ENLC Credit Facility could be foreclosed upon. At March 31, 2017 , ENLC was in compliance and expects to be in compliance with the covenants in the ENLC Credit Facility for at least the next twelve months. As of March 31, 2017 , there were no outstanding letters of credit and $43.5 million in outstanding borrowings under the ENLC Credit Facility, leaving approximately $206.5 million available for future borrowing based on the borrowing capacity of $250.0 million . ENLK Credit Facility ENLK has a $1.5 billion unsecured revolving credit facility (the “ENLK Credit Facility”), which includes a $500.0 million letter of credit subfacility. Under the ENLK Credit Facility, ENLK is permitted to (1) subject to certain conditions and the receipt of additional commitments by one or more lenders, increase the aggregate commitments under the ENLK Credit Facility by an additional amount not to exceed $500.0 million and (2) subject to certain conditions and the consent of the requisite lenders, on two separate occasions extend the maturity date of the ENLK Credit Facility by one year on each occasion. The ENLK Credit Facility contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining a ratio of consolidated indebtedness to consolidated EBITDA (which is defined in the ENLK Credit Facility and includes projected EBITDA from certain capital expansion projects) of no more than 5.0 to 1.0. If ENLK consummates one or more acquisitions, in which the aggregate purchase price is $50.0 million or more, ENLK can elect to increase the maximum allowed ratio of consolidated indebtedness to consolidated EBITDA to 5.5 to 1.0 for the quarter of the acquisition and the three following quarters. Borrowings under the ENLK Credit Facility bear interest at ENLK’s option at the Eurodollar Rate (the LIBOR Rate) plus an applicable margin (ranging from 1.00% to 1.75% ) or the Base Rate (the highest of the Federal Funds Rate plus 0.50% , the 30-day Eurodollar Rate plus 1.0% or the administrative agent’s prime rate) plus an applicable margin (ranging from zero percent to 0.75% ). The applicable margins vary depending on ENLK’s credit rating. If ENLK breaches certain covenants governing the ENLK Credit Facility, amounts outstanding under the ENLK Credit Facility, if any, may become due and payable immediately. At March 31, 2017 , ENLK was in compliance and expects to be in compliance with the covenants in the ENLK Credit Facility for at least the next twelve months. As of March 31, 2017 , there were $9.1 million in outstanding letters of credit and $330.0 million in outstanding borrowings under the ENLK Credit Facility, leaving approximately $1.2 billion available for future borrowing based on the borrowing capacity of $1.5 billion . All other material terms and conditions of the ENLK Credit Facility are described in Part II, “Item 8. Financial Statements and Supplementary Data—Note 6” in our Annual Report on Form 10-K for the year ended December 31, 2016 .

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	(7) Income Taxes Income taxes included in the consolidated financial statements were as follows for the periods presented (in millions): Three Months Ended 2017 2016 ENLC income tax expense $ 3.0 $ 0.2 Total income tax expense $ 3.0 $ 0.2 The following schedule reconciles total income tax expense and the amount calculated by applying the statutory U.S. federal tax rate to income before income taxes (in millions): Three Months Ended 2017 2016 Tax expense (benefit) at statutory federal rate (35%) $ 0.4 $ (160.5 ) State income taxes benefit, net of federal tax benefit — (14.9 ) Income tax expense from partnership 0.5 1.0 Unit-based compensation (1) 2.3 — Non-deductible expense related to asset impairment — 173.9 Other (0.2 ) 0.7 Total income tax expense $ 3.0 $ 0.2 (1) Relates to tax deficiencies recorded on vested units, which are recognized on the income statement in accordance with the adoption of ASU 2016-09.

Certain Provisions of the Partn

Certain Provisions of the Partnership Agreement	3 Months Ended
	Mar. 31, 2017
Partners' Capital [Abstract]
Certain Provisions of the Partnership Agreement	(8) Certain Provisions of the Partnership Agreement (a) Issuance of Common Units In November 2014, ENLK entered into an Equity Distribution Agreement (the “BMO EDA”) with BMO Capital Markets Corp., Merrill Lynch, Pierce, Fenner & Smith Incorporated, Citigroup Global Markets Inc., Jefferies LLC, Raymond James & Associates, Inc. and RBC Capital Markets, LLC (collectively, the “Sales Agents”) to sell up to $350.0 million in aggregate gross sales of ENLK’s common units from time to time through an “at the market” equity offering program. ENLK may also sell common units to any Sales Agent as principal for the Sales Agent’s own account at a price agreed upon at the time of sale. ENLK has no obligation to sell any of the common units under the BMO EDA and may at any time suspend solicitation and offers under the BMO EDA. For the three months ended March 31, 2017 , ENLK sold an aggregate of approximately 3.0 million common units under the BMO EDA, generating proceeds of approximately $55.2 million (net of approximately $0.6 million of commissions). ENLK used the net proceeds for general partnership purposes. As of March 31, 2017, approximately $92.0 million of gross common unit issuances remain available under the BMO EDA. (b) Distributions Unless restricted by the terms of the ENLK Credit Facility and/or the indentures governing ENLK’s unsecured senior notes, ENLK must make distributions of 100% of available cash, as defined in the partnership agreement, within 45 days following the end of each quarter. Distributions are made to the General Partner in accordance with its current percentage interest with the remainder to the common unitholders, subject to the payment of incentive distributions as described below to the extent that certain target levels of cash distributions are achieved. The General Partner was not entitled to its general partner or incentive distributions with respect to the ENLK Class C Common Units issued in kind. In addition, the General Partner is not entitled to its general partner or incentive distributions with respect to ENLK’s Preferred Units until such units are converted to common units. The General Partner owns the general partner interest in ENLK and all of its incentive distribution rights. The General Partner is entitled to receive incentive distributions if the amount ENLK distributes with respect to any quarter exceeds levels specified in its partnership agreement. Under the quarterly incentive distribution provisions, generally the General Partner is entitled to 13.0% of amounts ENLK distributes in excess of $0.25 per unit, 23.0% of the amounts ENLK distributes in excess of $0.3125 per unit and 48.0% of amounts ENLK distributes in excess of $0.375 per unit. Distributions on the Preferred Units for the three months ended December 31, 2016 , were paid-in kind through the issuance of 1,130,131 additional Preferred Units on February 13, 2017. A distribution on the Preferred Units was declared for the three months ended March 31, 2017 , which will result in the issuance of 1,154,147 additional Preferred Units on May 12, 2017 . A summary of ENLK’s distribution activity relating to the common units for the three months ended March 31, 2017 and 2016 , respectively, is provided below: Declaration period Distribution/unit Date paid/payable 2017 Fourth Quarter of 2016 $ 0.39 February 13, 2017 First Quarter of 2017 $ 0.39 May 12, 2017 2016 Fourth Quarter of 2015 $ 0.39 February 11, 2016 First Quarter of 2016 $ 0.39 May 12, 2016 (c) Allocation of ENLK Income Net income is allocated to the General Partner in an amount equal to its incentive distribution rights as described in (b) above. The General Partner’s share of net income consists of incentive distribution rights to the extent earned, a deduction for unit-based compensation attributable to ENLC’s restricted units, the percentage interest of ENLK’s net income adjusted for ENLC’s unit-based compensation specifically allocated to our General Partner. The net income allocated to the General Partner is as follows (in millions): Three Months Ended 2017 2016 Income allocation for incentive distributions $ 14.7 $ 13.8 Unit-based compensation attributable to ENLC’s restricted units (8.8 ) (4.0 ) General Partner share of net income (loss) — (2.4 ) General Partner interest in net income $ 5.9 $ 7.4

Earnings Per Unit and Dilution

Earnings Per Unit and Dilution Computations	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Earnings Per Unit and Dilution Computations	(9) Earnings Per Unit and Dilution Computations As required under ASC 260, Earnings Per Share , unvested share-based payments that entitle employees to receive non-forfeitable distributions are considered participating securities for earnings per unit calculations. The following table reflects the computation of basic and diluted earnings per limited partner units for the periods presented (in millions, except per unit amounts): Three Months Ended March 31, 2017 2016 EnLink Midstream, LLC interest in net loss $ (1.9 ) $ (457.6 ) Distributed earnings allocated to: Common units (1) $ 45.9 $ 45.6 Unvested restricted units (1) 0.6 0.5 Total distributed earnings $ 46.5 $ 46.1 Undistributed loss allocated to: Common units $ (47.8 ) $ (498.5 ) Unvested restricted units (0.6 ) (5.2 ) Total undistributed loss $ (48.4 ) $ (503.7 ) Net loss allocated to: Common units $ (1.9 ) $ (452.9 ) Unvested restricted units — (4.7 ) Total net loss $ (1.9 ) $ (457.6 ) Basic and diluted net loss per unit: Basic $ (0.01 ) $ (2.56 ) Diluted $ (0.01 ) $ (2.56 ) (1) For the three months ended March 31, 2017 and 2016 , represents a declared distribution of $0.255 per unit payable May 15, 2017 and a declared distribution of $0.255 per unit payable May 13, 2016, respectively. A summary of our distribution activity relating to the ENLC common units for the three months ended March 31, 2017 and 2016 , respectively, is provided below: Declaration period Distribution/unit Date paid/payable 2017 Fourth Quarter of 2016 $ 0.255 February 14, 2017 First Quarter of 2017 $ 0.255 May 15, 2017 2016 Fourth Quarter of 2015 $ 0.255 February 12, 2016 First Quarter of 2016 $ 0.255 May 13, 2016 The following are the unit amounts used to compute the basic and diluted earnings per unit for the periods presented (in millions): Three Months Ended March 31, 2017 2016 Basic and diluted earnings per unit: Weighted average common units outstanding 180.2 178.7 Diluted weighted average units outstanding: Weighted average basic common units outstanding 180.2 178.7 Dilutive effect of restricted incentive units issued — — Total weighted average diluted common units outstanding 180.2 178.7 All outstanding units were included in the computation of diluted earnings per unit and weighted based on the number of days such units were outstanding during the periods presented. All common unit equivalents were antidilutive for the three months ended March 31, 2017 and 2016 because a net loss existed for the corresponding periods.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(10) Asset Retirement Obligations The schedule below summarizes the changes in our asset retirement obligations (in millions): Three Months Ended March 31, 2017 Balance, beginning of period $ 13.5 Accretion expense 0.2 Balance, end of period $ 13.7 Asset retirement obligations of $13.7 million and $13.5 million were included in “Asset retirement obligations” as non-current liabilities on the consolidated balance sheets as of March 31, 2017 and December 31, 2016 , respectively.

Investment in Unconsolidated Af

Investment in Unconsolidated Affiliates	3 Months Ended
	Mar. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Affiliates	(11) Investment in Unconsolidated Affiliates Our unconsolidated investments consisted of: • a contractual right to the economic benefits and burdens associated with Devon’s 38.75% ownership interest in Gulf Coast Fractionators (“GCF”) at March 31, 2017 and December 31, 2016 ; • an approximate 30.0% ownership in Cedar Cove Midstream LLC (“Cedar Cove JV”) at March 31, 2017 and December 31, 2016 . On November 9, 2016, we formed the Cedar Cove JV with Kinder Morgan, Inc., which consists of gathering and compression assets in Blaine County, Oklahoma, the heart of the Sooner Trend Anadarko Basin Canadian and Kingfisher Counties play; • an approximate 31.0% common unit ownership interest in Howard Energy Partners (“HEP”) at December 31, 2016 . In December 2016, we entered into an agreement to sell our ownership interest in HEP. We finalized the sale in the first quarter of 2017 and received net proceeds of $189.7 million . The following table shows the activity related to our investment in unconsolidated affiliates for the periods indicated (in millions): Gulf Coast Fractionators Howard Energy Partners Cedar Cove JV Total Three Months Ended March 31, 2017 Contributions $ — $ — $ 6.0 $ 6.0 Distributions $ 2.7 $ — $ 0.2 $ 2.9 Equity in income (loss) (1) $ 4.0 $ (3.4 ) $ 0.1 $ 0.7 March 31, 2016 Contributions $ — $ 7.1 $ — $ 7.1 Distributions $ 3.0 $ 6.2 $ — $ 9.2 Equity in loss $ (1.7 ) $ (0.7 ) $ — $ (2.4 ) (1) Includes a loss of $3.4 million for the three months ended March 31, 2017 from the sale of HEP in March 2017. The following table shows the balances related to our investment in unconsolidated affiliates as of March 31, 2017 and December 31, 2016 (in millions): March 31, 2017 December 31, 2016 Gulf Coast Fractionators $ 49.8 $ 48.5 Howard Energy Partners — 193.1 Cedar Cove JV 34.7 28.8 Total investment in unconsolidated affiliates $ 84.5 $ 270.4

Employee Incentive Plans

Employee Incentive Plans	3 Months Ended
	Mar. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Employee Incentive Plans	(12) Employee Incentive Plans (a) Long-Term Incentive Plans ENLC and ENLK each have similar unit-based compensation payment plans for officers and employees. ENLC grants unit-based awards under the EnLink Midstream, LLC 2014 Long-Term Incentive Plan (the “LLC Plan”) , and ENLK grants unit-based awards under the amended and restated EnLink Midstream GP, LLC Long-Term Incentive Plan (the “GP Plan”) . We account for unit-based compensation in accordance with ASC 718, Stock Compensation (“ASC 718”), which requires that compensation related to all unit-based awards be recognized in the consolidated financial statements. Unit-based compensation cost is recognized as expense over each award’s requisite service period with a corresponding increase to equity or liability based on the terms of each award and the appropriate accounting treatment under ASC 718. Unit-based compensation associated with ENLC’s unit-based compensation plan awarded to our officers and employees is recorded by ENLK since ENLC has no substantial or managed operating activities other than its interests in ENLK and EnLink Oklahoma T.O. Amounts recognized in the consolidated financial statements with respect to these plans are as follows (in millions): Three Months Ended March 31, 2017 2016 Cost of unit-based compensation charged to general and administrative expense $ 14.4 $ 6.3 Cost of unit-based compensation charged to operating expense 5.0 1.7 Total unit-based compensation expense $ 19.4 $ 8.0 Interest of non-controlling partners in unit-based compensation $ 7.3 $ 2.9 Amount of related income tax expense recognized in net income $ 4.6 $ 1.9 (b) EnLink Midstream Partners, LP Restricted Incentive Units ENLK restricted incentive units are valued at their fair value at the date of grant, which is equal to the market value of common units on such date. A summary of the restricted incentive unit activity for the three months ended March 31, 2017 is provided below: Three Months Ended EnLink Midstream Partners, LP Restricted Incentive Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 2,024,820 $ 19.05 Granted (1) 822,865 18.46 Vested (1)(2) (795,188 ) 25.84 Forfeited (6,997 ) 16.87 Non-vested, end of period 2,045,500 $ 16.18 Aggregate intrinsic value, end of period (in millions) $ 37.4 (1) Restricted incentive units were issued in the first quarter of 2017 to officers and other employees. These restricted incentive units typically vest at the end of three years. In March 2017, ENLK issued 262,288 restricted incentive units with a fair value of $5.1 million to officers and certain employees as bonus payments for 2016, and these restricted incentive units vested immediately and are included in the restricted incentive units granted and vested line items. (2) Vested units include 258,145 units withheld for payroll taxes paid on behalf of employees. A summary of the restricted incentive units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) for the three months ended March 31, 2017 and 2016 , respectively, is provided below (in millions): Three Months Ended March 31, EnLink Midstream Partners, LP Restricted Incentive Units: 2017 2016 Aggregate intrinsic value of units vested $ 15.3 $ 3.7 Fair value of units vested $ 20.5 $ 9.0 As of March 31, 2017 , there was $20.7 million of unrecognized compensation cost related to non-vested ENLK restricted incentive units for officers and employees. That cost is expected to be recognized over a weighted-average period of 2.0 years . (c) EnLink Midstream Partners, LP Performance Units For the three months ended March 31, 2017 , the General Partner and our Managing Member granted performance awards under the GP Plan and the LLC Plan, respectively. The performance award agreements provide that the vesting of restricted incentive units granted thereunder is dependent on the achievement of certain total shareholder return (“TSR”) performance goals relative to the TSR achievement of a peer group of companies (the “Peer Companies”) over the applicable performance period. The performance award agreements contemplate that the Peer Companies for an individual performance award (the “Subject Award”) are the companies comprising the Alerian MLP Index for Master Limited Partnerships (“AMZ”), excluding ENLC and ENLK (collectively, “EnLink”), on the grant date for the Subject Award. The performance units will vest based on the percentile ranking of the average of ENLC’s and ENLK’s TSR achievement (“EnLink TSR”) for the applicable performance period relative to the TSR achievement of the Peer Companies. At the end of the vesting period, recipients receive distribution equivalents, if any, with respect to the number of performance units vested. The vesting of units range from zero to 200% of the units granted depending on the EnLink TSR as compared to the TSR of the Peer Companies on the vesting date. The fair value of each performance unit is estimated as of the date of grant using a Monte Carlo simulation with the following assumptions used for all performance unit grants made under the plan: (i) a risk-free interest rate based on United States Treasury rates as of the grant date; (ii) a volatility assumption based on the historical realized price volatility of ENLK’s common units and the designated peer group securities; (iii) an estimated ranking of ENLK among the designated peer group; and (iv) the distribution yield. The fair value of the performance unit on the date of grant is expensed over a vesting period of approximately three years . The following table presents a summary of the grant-date fair values of performance units granted and the related assumptions: EnLink Midstream Partners, LP Performance Units: March 2017 Beginning TSR Price $ 17.55 Risk-free interest rate 1.62 % Volatility factor 43.94 % Distribution yield 8.7 % The following table presents a summary of the performance units: Three Months Ended EnLink Midstream Partners, LP Performance Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 408,637 $ 11.53 Granted 176,648 25.73 Forfeited — — Non-vested, end of period 585,285 $ 15.82 Aggregate intrinsic value, end of period (in millions) $ 10.7 As of March 31, 2017 , there was $8.0 million of unrecognized compensation expense that related to non-vested ENLK performance units. That cost is expected to be recognized over a weighted-average period of 2.3 years . (d) EnLink Midstream, LLC Restricted Incentive Units ENLC restricted incentive units are valued at their fair value at the date of grant, which is equal to the market value of the ENLC common units on such date. A summary of the restricted incentive unit activity for the three months ended March 31, 2017 is provided below: Three Months Ended EnLink Midstream, LLC Restricted Incentive Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 1,897,298 $ 19.96 Granted (1) 781,842 19.29 Vested (1)(2) (726,692 ) 28.07 Forfeited (6,706 ) 17.58 Non-vested, end of period 1,945,742 $ 16.67 Aggregate intrinsic value, end of period (in millions) $ 37.7 (1) Restricted incentive units were issued in the first quarter of 2017 to officers and other employees. These restricted incentive units typically vest at the end of three years. In March 2017, we issued 258,606 restricted incentive units with a fair value of $5.0 million to officers and certain employees as bonus payments for 2016, and these restricted incentive units vested immediately and are included in the restricted incentive units granted and vested line items. (2) Vested units include 224,709 units withheld for payroll taxes paid on behalf of employees. A summary of the restricted incentive units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) for the three months ended March 31, 2017 and 2016 , respectively, are provided below (in millions): Three Months Ended March 31, EnLink Midstream LLC Restricted Incentive Units: 2017 2016 Aggregate intrinsic value of units vested $ 14.3 $ 3.8 Fair value of units vested $ 20.4 $ 11.8 As of March 31, 2017 , there was $20.2 million of unrecognized compensation costs related to non-vested ENLC restricted incentive units for directors, officers and employees. The cost is expected to be recognized over a weighted-average period of 2.0 years . (e) EnLink Midstream, LLC’s Performance Units For the three months ended March 31, 2017 , ENLC granted performance awards under the LLC Plan. At the end of the vesting period, recipients receive distribution equivalents, if any, with respect to the number of performance units vested. The vesting of units range from zero to 200% of the units granted depending on the EnLink TSR as compared to the TSR of the Peer Companies on the vesting date. The fair value of each performance unit is estimated as of the date of grant using a Monte Carlo simulation with the following assumptions used for all performance unit grants made under the plan: (i) a risk-free interest rate based on United States Treasury rates as of the grant date; (ii) a volatility assumption based on the historical realized price volatility of ENLC’s common units and the designated peer group securities; (iii) an estimated ranking of ENLC among the designated peer group and (iv) the distribution yield. The fair value of the unit on the date of grant is expensed over a vesting period of approximately three years . The following table presents a summary of the grant-date fair values of performance units granted and the related assumptions: EnLink Midstream, LLC Performance Units: March 2017 Beginning TSR Price $ 18.29 Risk-free interest rate 1.62 % Volatility factor 52.07 % Distribution yield 5.4 % The following table presents a summary of the performance units: Three Months Ended EnLink Midstream, LLC Performance Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 384,264 $ 19.30 Granted 164,575 28.77 Forfeited — — Non-vested, end of period 548,839 $ 22.14 Aggregate intrinsic value, end of period (in millions) $ 10.6 As of March 31, 2017 , there was $8.1 million of unrecognized compensation expense that related to non-vested ENLC performance units. That cost is expected to be recognized over a weighted-average period of 2.3 years .

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	(13) Derivatives Commodity Swaps We manage our exposure to changes in commodity prices by hedging the impact of market fluctuations. Swaps are used to manage and hedge price and location risk related to these market exposures. Swaps are also used to manage margins on offsetting fixed-price purchase or sale commitments for physical quantities of crude, condensate, natural gas and NGLs. We do not designate transactions as cash flow or fair value hedges for hedge accounting treatment under ASC 815, Derivatives and Hedging . Therefore, changes in the fair value of our derivatives are recorded in revenue in the period incurred. In addition, our risk management policy does not allow us to take speculative positions with our derivative contracts. We commonly enter into index (float-for-float) or fixed-for-float swaps in order to mitigate our cash flow exposure to fluctuations in the future prices of natural gas, NGLs and crude oil. For natural gas, index swaps are used to protect against the price exposure of daily priced gas versus first-of-month priced gas. They are also used to hedge the basis location price risk resulting from supply and markets being priced on different indices. For natural gas, NGLs, condensate and crude, fixed-for-float swaps are used to protect cash flows against price fluctuations: (1) where we receive a percentage of liquids as a fee for processing third-party gas or where we receive a portion of the proceeds of the sales of natural gas and liquids as a fee, (2) in the natural gas processing and fractionation components of our business and (3) where we are mitigating the price risk for product held in inventory or storage. The components of gain (loss) on derivative activity in the consolidated statements of operations related to commodity swaps are (in millions): Three Months Ended March 31, 2017 2016 Change in fair value of derivatives $ 5.3 $ (6.0 ) Realized gain (loss) on derivatives (2.5 ) 5.6 Gain (loss) on derivative activity $ 2.8 $ (0.4 ) The fair value of derivative assets and liabilities related to commodity swaps are as follows (in millions): March 31, 2017 December 31, 2016 Fair value of derivative assets — current $ 2.1 $ 1.3 Fair value of derivative assets — long-term 0.1 — Fair value of derivative liabilities — current (2.9 ) (7.6 ) Fair value of derivative liabilities — long-term (0.3 ) — Net fair value of derivatives $ (1.0 ) $ (6.3 ) Assets and liabilities related to our derivative contracts are included in the fair value of derivative assets and liabilities and the change in fair value of these contracts are recorded at net as a gain (loss) on derivative activity in the consolidated statements of operations. We estimate the fair value of all of our derivative contracts using actively-quoted prices. Set forth below is the summarized notional volumes and fair values of all instruments held for price risk management purposes and related physical offsets at March 31, 2017 (in millions). The remaining term of the contracts extend no later than October 2018. March 31, 2017 Commodity Instruments Unit Volume Fair Value NGL (short contracts) Swaps Gallons (32.9 ) $ (0.3 ) NGL (long contracts) Swaps Gallons 12.8 (0.2 ) Natural Gas (short contracts) Swaps MMBtu (15.4 ) (0.3 ) Natural Gas (long contracts) Swaps MMBtu 15.1 (0.4 ) Condensate (short contracts) Swaps MMbbls — 0.1 Condensate (long contracts) Swaps MMbbls — 0.1 Total fair value of derivatives $ (1.0 ) On all transactions where we are exposed to counterparty risk, we analyze the counterparty’s financial condition prior to entering into an agreement, establish limits and monitor the appropriateness of these limits on an ongoing basis. We primarily deal with two types of counterparties, financial institutions and other energy companies, when entering into financial derivatives on commodities. We have entered into Master International Swaps and Derivatives Association Agreements (“ISDAs”) that allow for netting of swap contract receivables and payables in the event of default by either party. If our counterparties failed to perform under existing swap contracts, our maximum loss of $2.2 million as of March 31, 2017 would be reduced to $0.4 million due to the offsetting of gross fair value payables against gross fair value receivables as allowed by the ISDAs.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements	(14) Fair Value Measurements ASC 820, Fair Value Measurements and Disclosures (“ASC 820”), sets forth a framework for measuring fair value and required disclosures about fair value measurements of assets and liabilities. Fair value under ASC 820 is defined as the price at which an asset could be exchanged in a current transaction between knowledgeable, willing parties. A liability’s fair value is defined as the amount that would be paid to transfer the liability to a new obligor, not the amount that would be paid to settle the liability with the creditor. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, use of unobservable prices or inputs are used to estimate the current fair value, often using an internal valuation model. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the item being valued. ASC 820 established a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. Our derivative contracts primarily consist of commodity swap contracts, which are not traded on a public exchange. The fair values of commodity swap contracts are determined using discounted cash flow techniques. The techniques incorporate Level 1 and Level 2 inputs for future commodity prices that are readily available in public markets or can be derived from information available in publicly-quoted markets. These market inputs are utilized in the discounted cash flow calculation considering the instrument’s term, notional amount, discount rate and credit risk and are classified as Level 2 in hierarchy. Net assets (liabilities) measured at fair value on a recurring basis are summarized below (in millions): Level 2 March 31, 2017 December 31, 2016 Commodity Swaps (1) $ (1.0 ) $ (6.3 ) Total $ (1.0 ) $ (6.3 ) (1) The fair values of derivative contracts included in assets or liabilities for risk management activities represent the amount at which the instruments could be exchanged in a current arms-length transaction adjusted for our credit risk and/or the counterparty credit risk as required under ASC 820. Fair Value of Financial Instruments The estimated fair value of our financial instruments has been determined using available market information and valuation methodologies. Considerable judgment is required to develop the estimates of fair value; thus, the estimates provided below are not necessarily indicative of the amount we could realize upon the sale or refinancing of such financial instruments (in millions): March 31, 2017 December 31, 2016 Carrying Value Fair Value Carrying Value Fair Value Long-term debt (1) $ 3,521.1 $ 3,543.1 $ 3,295.8 $ 3,253.6 Installment Payables $ 230.1 $ 232.9 $ 473.2 $ 476.6 Obligations under capital lease $ 5.1 $ 4.3 $ 6.6 $ 6.1 (1) The carrying values of long-term debt are reduced by debt issuance costs of $23.8 million and $24.6 million at March 31, 2017 and December 31, 2016 , respectively. The respective fair values do not factor in debt issuance costs. The carrying amounts of our cash and cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term maturities of these assets and liabilities. ENLK had $330.0 million and $120.0 million in outstanding borrowings under the ENLK Credit Facility as of March 31, 2017 and December 31, 2016 , respectively. ENLC had $43.5 million and $27.8 million in outstanding borrowings under the ENLC Credit Facility as of March 31, 2017 and December 31, 2016 , respectively. As borrowings under the credit facilities accrue interest under floating interest rate structures, the carrying value of such indebtedness approximates fair value for the amounts outstanding under the credit facilities. As of March 31, 2017 and December 31, 2016 , ENLK had total borrowings under senior unsecured notes of $3.1 billion , maturing between 2019 and 2045 with fixed interest rates ranging from 2.7% to 7.1% . The fair values of all senior unsecured notes and installment payables as of March 31, 2017 and December 31, 2016 were based on Level 2 inputs from third-party market quotations. The fair values of obligations under capital leases were calculated using Level 2 inputs from third-party banks.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	(15) Commitments and Contingencies (a) Severance and Change in Control Agreements Certain members of our management are parties to severance and change of control agreements with EnLink Midstream Operating, LP. The severance and change in control agreements provide those individuals with severance payments in certain circumstances and prohibit such individuals from, among other things, competing with the General Partner or its affiliates during his or her employment. In addition, the severance and change of control agreements prohibit subject individuals from, among other things, disclosing confidential information about the General Partner or its affiliates or interfering with a client or customer of the General Partner or its affiliates, in each case during his or her employment and for certain periods (including indefinite periods) following the termination of such person’s employment. (b) Environmental Issues The operation of pipelines, plants and other facilities for the gathering, processing, transmitting or disposing of natural gas, NGLs, crude oil, condensate, brine and other products is subject to stringent and complex laws and regulations pertaining to health, safety and the environment. As an owner, partner or operator of these facilities, we must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants, and other facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our results of operations, financial condition or cash flows. In the third quarter of 2016, in connection with the transition to our operational control of E2 Appalachian Compression, LLC and in preparation to commence operational control of E2 Ohio Compression, LLC, we discovered instances of noncompliance with air regulations and permits. This noncompliance was self-reported to the Ohio Environmental Protection Agency (“OEPA”), resulting in the issuance of notices of violations (“NOVs”). We have taken appropriate measures to achieve compliance with applicable requirements, and we are working with the OEPA on a settlement agreement for the NOVs, which we believe will not include any fines or penalties that would be material to our results of operations. On July 29, 2016, after concluding a multi-year internal environmental compliance assessment of our Louisiana operations, we commenced discussions with the Louisiana Department of Environmental Quality (“LDEQ”) relating to a global settlement to resolve environmental noncompliance discovered or investigated during our assessment involving several of our Louisiana facilities and notices of potential violation and NOVs received from the LDEQ. We have taken appropriate measures to resolve all instances of noncompliance, and we continue to work with the LDEQ with respect to the proposed global settlement, which we believe will not include any fines or penalties that would be material to our results of operations. Lastly, we continue to work with Pipeline and Hazardous Materials Safety Administration regarding the notice of potential violation discussed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2016 . (c) Litigation Contingencies We are involved in various litigation and administrative proceedings arising in the normal course of business. In the opinion of management, any liabilities that may result from these claims would not individually or in the aggregate have a material adverse effect on our financial position, results of operations or cash flows. At times, our subsidiaries acquire pipeline easements and other property rights by exercising rights of eminent domain and common carrier. As a result, from time to time we (or our subsidiaries) are a party to a number of lawsuits under which a court will determine the value of pipeline easements or other property interests obtained by our subsidiaries by condemnation. Damage awards in these suits should reflect the value of the property interest acquired and the diminution in the value of the remaining property owned by the landowner. However, some landowners have alleged unique damage theories to inflate their damage claims or assert valuation methodologies that could result in damage awards in excess of the amounts anticipated. Although it is not possible to predict the ultimate outcomes of these matters, we do not expect that awards in these matters will have a material adverse impact on our consolidated results of operations, financial condition or cash flows. We (or our subsidiaries) are defending lawsuits filed by owners of property located near processing facilities or compression facilities constructed by us as part of our systems. The suits generally allege that the facilities create a private nuisance and have damaged the value of surrounding property. Claims of this nature have arisen as a result of the industrial development of natural gas gathering, processing and treating facilities in urban and occupied rural areas. In July 2013, the Board of Commissioners for the Southeast Louisiana Flood Protection Authority for New Orleans and surrounding areas filed a lawsuit against approximately 100 energy companies, seeking, among other relief, restoration of wetlands allegedly lost due to historic industry operations in those areas. The suit was filed in Louisiana state court in New Orleans, but was removed to the United States District Court for the Eastern District of Louisiana. The amount of damages is unspecified. Our subsidiary, EnLink LIG, LLC, is one of the named defendants as the owner of pipelines in the area. On February 13, 2015, the court granted defendants’ joint motion to dismiss and dismissed the plaintiff’s claims with prejudice. Plaintiffs have appealed the matter to the United States Court of Appeals for the Fifth Circuit. On March 3, 2017, the Court of Appeals affirmed the district court’s dismissal of the plaintiff’s claims. On March 17, 2017, the plaintiff filed a petition for rehearing en banc. On April 12, 2017, the Court of Appeals denied the plaintiffs petition for rehearing. We intend to continue vigorously defending the case. The success of the plaintiffs’ appeal as well as our costs and legal exposure, if any, related to the lawsuit are not currently determinable. We own and operate a high-pressure pipeline and underground natural gas and NGL storage reservoirs and associated facilities near Bayou Corne, Louisiana. In August 2012, a large sinkhole formed in the vicinity of this pipeline and underground storage reservoirs, resulting in damage to certain of our facilities. We are seeking to recover our losses from responsible parties. We sued Texas Brine Company, LLC (“Texas Brine”), the operator of a failed cavern in the area and its insurers, seeking recovery for these losses, as well as other parties we alleged contributed to the formation of the sinkhole. In August 2014, we received a partial settlement with respect to our claims in the amount of $6.1 million . In March 2017, we received an additional settlement payment of $17.5 million , which was recognized in “Gain on litigation settlement” in the consolidated statement of operations for the three months ended March 31, 2017. Additional claims remain outstanding. We also filed a claim with our insurers, which our insurers denied. We disputed the denial and sued our insurers. We cannot give assurance that we will be able to fully recover our losses through insurance recovery or claims against responsible parties. In June 2014, a group of landowners in Assumption Parish, Louisiana added our subsidiary, EnLink Processing Services, LLC, as a defendant in a pending lawsuit in the 23 rd Judicial Court, Assumption Parish, Louisiana they had filed against other defendants relating to claims arising from the Bayou Corne Sinkhole. Plaintiffs alleged that EnLink Processing Services, LLC’s negligence contributed to the formation of the sinkhole. The amount of damages was unspecified. EnLink Processing Services, LLC reached a settlement with the plaintiffs in February 2017, funded by EnLink Processing Services, LLC’s insurance carriers. The plaintiffs’ claims against EnLink Processing Services, LLC were dismissed with prejudice in March 2017.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Segment Information	(16) Segment Information Identification of the majority of our operating segments is based principally upon geographic regions served. Our reportable segments consist of the following: natural gas gathering, processing, transmission and fractionation operations located in north Texas and the Permian Basin in west Texas (“Texas”), the pipelines and processing plants located in Louisiana and NGL assets located in south Louisiana (“Louisiana”), natural gas gathering and processing operations located throughout Oklahoma (“Oklahoma”) and crude rail, truck, pipeline and barge facilities in west Texas, south Texas, Louisiana and the Ohio River Valley (“Crude and Condensate”). Operating activity for intersegment eliminations is shown in the Corporate segment. Our sales are derived from external domestic customers. We evaluate the performance of our operating segments based on operating revenues and segment profits. Corporate assets consist primarily of cash, property and equipment, including software, for general corporate support, debt financing costs and unconsolidated affiliate investments in GCF and the Cedar Cove JV. As of December 31, 2016, our Corporate assets included our unconsolidated affiliate investment in HEP. In December 2016, we entered into an agreement to sell our ownership interest in HEP, and we finalized the sale during the first quarter of 2017. Summarized financial information for our reportable segments is shown in the following table (in millions): Texas Louisiana Oklahoma Crude and Condensate Corporate Totals Three Months Ended March 31, 2017 Product sales $ 85.1 $ 544.5 $ 14.5 $ 345.9 $ — $ 990.0 Product sales—related parties 106.5 10.2 64.4 0.8 (139.2 ) 42.7 Midstream services 27.8 53.1 27.9 18.6 — 127.4 Midstream services—related parties 105.1 29.0 49.4 3.3 (27.8 ) 159.0 Cost of sales (179.2 ) (564.7 ) (88.7 ) (336.7 ) 167.0 (1,002.3 ) Operating expenses (43.9 ) (25.4 ) (14.1 ) (20.7 ) — (104.1 ) Gain on derivative activity — — — — 2.8 2.8 Segment profit $ 101.4 $ 46.7 $ 53.4 $ 11.2 $ 2.8 $ 215.5 Depreciation and amortization $ (49.8 ) $ (28.1 ) $ (36.5 ) $ (11.5 ) $ (2.4 ) $ (128.3 ) Goodwill $ 232.0 $ — $ 190.3 $ — $ 1,119.9 $ 1,542.2 Capital expenditures $ 28.3 $ 32.7 $ 140.7 $ 37.4 $ 9.0 $ 248.1 Three Months Ended March 31, 2016 Product sales $ 62.5 $ 287.7 $ 7.8 $ 230.5 $ — $ 588.5 Product sales—related parties 37.3 7.4 10.6 0.2 (31.0 ) 24.5 Midstream services 27.4 55.2 15.1 16.8 — 114.5 Midstream services—related parties 110.3 12.7 45.0 5.2 (10.6 ) 162.6 Cost of sales (91.3 ) (302.1 ) (19.3 ) (215.1 ) 41.6 (586.2 ) Operating expenses (39.3 ) (23.3 ) (12.8 ) (22.8 ) — (98.2 ) Loss on derivative activity — — — — (0.4 ) (0.4 ) Segment profit (loss) $ 106.9 $ 37.6 $ 46.4 $ 14.8 $ (0.4 ) $ 205.3 Depreciation and amortization $ (46.2 ) $ (29.3 ) $ (33.8 ) $ (10.4 ) $ (2.2 ) $ (121.9 ) Impairments $ (473.1 ) $ — $ — $ (93.2 ) $ (307.0 ) $ (873.3 ) Goodwill $ 230.4 $ — $ 190.3 $ — $ 1,119.9 $ 1,540.6 Capital expenditures $ 23.3 $ 22.7 $ 69.2 $ 3.3 $ 1.9 $ 120.4 The table below represents information about segment assets as of March 31, 2017 and December 31, 2016 (in millions): Segment Identifiable Assets: March 31, 2017 December 31, 2016 Texas $ 3,132.6 $ 3,142.6 Louisiana 2,312.7 2,349.3 Oklahoma 2,629.8 2,524.5 Crude and Condensate 861.9 836.8 Corporate 1,240.5 1,422.7 Total identifiable assets $ 10,177.5 $ 10,275.9 The following table reconciles the segment profits reported above to the operating income (loss) as reported in the consolidated statements of operations (in millions): Three Months Ended March 31, 2017 2016 Segment profits $ 215.5 $ 205.3 General and administrative expenses (36.1 ) (35.1 ) Gain (loss) on disposition of assets (5.1 ) 0.2 Depreciation and amortization (128.3 ) (121.9 ) Impairments (7.0 ) (873.3 ) Gain on litigation settlement 17.5 $ — Operating income (loss) $ 56.5 $ (824.8 )

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(17) Supplemental Cash Flow Information The following schedule summarizes non-cash financing activities for the periods presented (in millions): Three Months Ended March 31, 2017 2016 Non-cash financing activities: Non-cash issuance of ENLC common units (1) $ — $ 214.9 Installment payable, net of discount of $79.1 million (2) — 420.9 (1) Non-cash ENLC common units were issued as partial consideration for the acquisition of EnLink Oklahoma T.O. assets. See “ Note 3—Acquisition ” for further discussion. (2) ENLK incurred installment purchase obligations, net of discount, payable to the seller in connection with the EnLink Oklahoma T.O. assets. ENLK paid the first installment on January 6, 2017 and will pay the final installment no later than January 7, 2018. See “ Note 3—Acquisition ” for further discussion.

Other Information

Other Information	3 Months Ended
	Mar. 31, 2017
Other Liabilities Disclosure [Abstract]
Other Information	(18) Other Information The following table presents additional detail for other current liabilities, which consists of the following (in millions): March 31, 2017 December 31, 2016 Accrued interest $ 58.4 $ 34.2 Accrued wages and benefits, including taxes 9.2 19.0 Accrued ad valorem taxes 13.0 23.5 Capital expenditure accruals 56.3 64.6 Onerous performance obligations 15.8 15.9 Other 61.6 60.3 Other current liabilities $ 214.3 $ 217.5

Subsequent Event

Subsequent Event	3 Months Ended
	Mar. 31, 2017
Subsequent Events [Abstract]
Subsequent Event	(19) Subsequent Event On April 3, 2017, ENLK issued notice to redeem its 2022 notes. The 2022 notes will be redeemed on June 1, 2017 at 103.6% of the principal amount, plus accrued unpaid interest, for aggregate cash consideration of $174.1 million , and we expect to recognize a gain on extinguishment of debt of approximately $3.2 million for the three months ending June 30, 2017.

Significant Accounting Polici27

Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2017
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying consolidated financial statements are prepared in accordance with the instructions to Form 10-Q, are unaudited and do not include all the information and disclosures required by generally accepted accounting principles in the United States of America (“GAAP”) for complete financial statements. All adjustments that, in the opinion of management, are necessary for a fair presentation of the results of operations for the interim periods have been made and are of a recurring nature unless otherwise disclosed herein. The results of operations for such interim periods are not necessarily indicative of results of operations for a full year. All significant intercompany balances and transactions have been eliminated in consolidation.
Adopted Accounting Standards; Accounting Standards to be Adopted in Future Periods	Adopted Accounting Standards In March 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”), which simplifies several aspects related to the accounting for share-based payment transactions. Effective January 1, 2017, we adopted ASU 2016-09. We prospectively adopted the guidance that requires excess tax benefits and deficiencies be recognized on the income statement. The new cash flow statement guidance requires the presentation of excess tax benefits and deficiencies as an operating activity and the presentation of cash paid by an employer when directly withholding shares for tax-withholding purposes as a financing activity, and this treatment is consistent with our historical accounting treatment. Finally, we elected to estimate the number of awards that are expected to vest, which is consistent with our historical accounting treatment. The adoption of the new guidance did not materially affect the consolidated statement of operations for the three months ended March 31, 2017 . In January 2017, the FASB issued ASU 2017-04, Intangibles — Goodwill and Other (Topic 350) — Simplifying the Test for Goodwill Impairment (“ASU 2017-04”). ASU 2017-04 simplifies the accounting for goodwill impairments by eliminating the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test referenced in Accounting Standards Codification (“ASC”) 350, Intangibles - Goodwill and Other (“ASC 350”). As a result, an entity should perform its annual, or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit’s fair value. However, the impairment loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including any interim impairment tests within those annual periods, with early application permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. In January 2017, we elected to early adopt ASU 2017-04, and the adoption had no impact on our consolidated financial statements. We will perform future goodwill impairment tests according to ASU 2017-04. (c) Accounting Standards to be Adopted in Future Periods In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) — Amendments to the FASB Accounting Standards Codification (“ASU 2016-02”). Lessees will need to recognize virtually all of their leases on the balance sheet by recording a right-of-use asset and lease liability. Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model and the new revenue recognition standard. Existing sale-leaseback guidance is replaced with a new model applicable to both lessees and lessors. Additional revisions have been made to embedded leases, reassessment requirements and lease term assessments including variable lease payment, discount rate and lease incentives. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018 including interim periods within those annual periods. Early adoption is permitted. Entities are required to adopt ASU 2016-02 using a modified retrospective transition. We are currently assessing the impact of adopting ASU 2016-02. This assessment includes the gathering and evaluation of our current lease contracts and the analysis of contracts that may contain lease components. While we cannot currently estimate the quantitative effect that ASU 2016-02 will have on our consolidated financial statements, the adoption of ASU 2016-02 will increase our asset and liability balances on the consolidated balance sheets due to the required recognition of right-of-use assets and corresponding lease liabilities for all lease obligations that are currently classified as operating leases. In addition, there are industry-specific concerns with the implementation of ASU 2016-02, including the application of ASU 2016-02 to contracts involving easements/right-of-ways, which will require further evaluation before we are able to fully assess the impact on our consolidated financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”), which established ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”). ASC 606 will replace existing revenue recognition requirements in GAAP and will require entities to recognize revenue at an amount that reflects the consideration to which we expect to be entitled in exchange for transferring goods or services to a customer. ASC 606 will also require significantly expanded disclosures regarding the qualitative and quantitative information of our nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In May 2016, the FASB issued ASU 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients (“ASU 2016-12”), which updated ASU 2014-09. ASU 2016-12 clarifies certain core recognition principles, including collectability, sales tax presentation, noncash consideration, contract modifications and completed contracts at transition and disclosures no longer required if the full retrospective transition method is adopted. ASU 2014-09 and ASU 2016-12 are effective for annual reporting periods beginning after December 15, 2017, including interim periods within those annual periods, and are to be applied using the modified retrospective or full retrospective transition methods, with early application permitted for annual reporting periods beginning after December 15, 2016. We plan to use the modified retrospective transition method and do not plan to early adopt ASC 606. We have aggregated and reviewed our contracts that are within the scope of ASC 606. Based on our evaluation to date, we do not anticipate this standard will have a material impact on our consolidated financial statements. We continue to evaluate the impacts ASC 606 will have on our disclosures.
Property, Plant and Equipment	Property, Plant & Equipment Gain or Loss on Disposition. We recognize any gain or loss upon the disposition or retirement of property, plant and equipment in operating income in the consolidated statement of operations. For the three months ended March 31, 2017 , we retired certain plant assets in the Permian Basin that were damaged by fire, which resulted in a loss on disposition of $5.1 million . Impairment Review. We evaluate our property, plant and equipment for potential impairment whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. The carrying amount of a long-lived asset is not recoverable when it exceeds the undiscounted sum of the future cash flows expected to result from the use and eventual disposition of the asset. Estimates of expected future cash flows represent management’s best estimate based on reasonable and supportable assumptions. When the carrying amount of a long-lived asset is not recoverable, an impairment loss is recognized equal to the excess of the asset’s carrying value over its fair value.

Acquisitions (Tables)

Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2017
Business Combinations [Abstract]
Schedule of Consideration and Fair Value of Identified Assets Received and Liabilities Assumed	The following table presents the consideration ENLC and ENLK paid and the fair value of the identified assets received and liabilities assumed at the acquisition date (in millions): Consideration: Cash $ 805.8 Issuance of common units 214.9 ENLK’s total installment payable, net of discount of $79.1 million assuming payments made on January 7, 2017 and 2018 420.9 Total consideration $ 1,441.6 Purchase Price Allocation: Assets acquired: Current assets (including $12.8 million in cash) $ 23.0 Property, plant and equipment 406.1 Intangibles 1,051.3 Liabilities assumed: Current liabilities (38.8 ) Total identifiable net assets $ 1,441.6

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Goodwill and Intangible Assets Disclosure [Abstract]
Summary of Changes in Carrying Value	The following table represents our change in carrying value of intangible assets (in millions): Gross Carrying Amount Accumulated Amortization Net Carrying Amount Three Months Ended March 31, 2017 Customer relationships, beginning of period $ 1,795.8 $ (171.6 ) $ 1,624.2 Amortization expense — (29.5 ) (29.5 ) Customer relationships, end of period $ 1,795.8 $ (201.1 ) $ 1,594.7
Schedule of Amortization Expense	The following table summarizes our estimated aggregate amortization expense for the next five years (in millions): 2017 (remaining) $ 88.4 2018 117.9 2019 117.9 2020 117.9 2021 117.9 Thereafter 1,034.7 Total $ 1,594.7

Long-Term Debt (Tables)

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Summary of Debt	As of March 31, 2017 and December 31, 2016 , long-term debt consisted of the following (in millions): March 31, 2017 December 31, 2016 Outstanding Principal Premium (Discount) Long-Term Debt Outstanding Principal Premium (Discount) Long-Term Debt ENLK credit facility due 2020 (1) $ 330.0 $ — $ 330.0 $ 120.0 $ — $ 120.0 ENLC credit facility due 2019 (2) 43.5 — 43.5 27.8 — 27.8 2.70% Senior unsecured notes due 2019 400.0 (0.2 ) 399.8 400.0 (0.3 ) 399.7 7.125% Senior unsecured notes due 2022 (3) 162.5 15.2 177.7 162.5 16.0 178.5 4.40% Senior unsecured notes due 2024 550.0 2.4 552.4 550.0 2.5 552.5 4.15% Senior unsecured notes due 2025 750.0 (1.1 ) 748.9 750.0 (1.1 ) 748.9 4.85% Senior unsecured notes due 2026 500.0 (0.6 ) 499.4 500.0 (0.7 ) 499.3 5.60% Senior unsecured notes due 2044 350.0 (0.2 ) 349.8 350.0 (0.2 ) 349.8 5.05% Senior unsecured notes due 2045 450.0 (6.6 ) 443.4 450.0 (6.6 ) 443.4 Debt classified as long-term $ 3,536.0 $ 8.9 $ 3,544.9 $ 3,310.3 $ 9.6 $ 3,319.9 Debt issuance cost (4) (23.8 ) (24.6 ) Long-term debt, net of unamortized issuance cost $ 3,521.1 $ 3,295.3 (1) Bears interest based on Prime and/or LIBOR plus an applicable margin. The effective interest rate was 3.0% and 2.3% at March 31, 2017 and December 31, 2016 , respectively. (2) Bears interest based on Prime and/or LIBOR plus an applicable margin. The effective interest rate was 3.1% and 3.4% at March 31, 2017 and December 31, 2016 , respectively. (3) On April 3, 2017, ENLK issued notice to redeem its 7.125% senior unsecured notes due 2022 (the “2022 notes”). The 2022 notes will be redeemed on June 1, 2017 at 103.6% of the principal amount, plus accrued unpaid interest, for aggregate cash consideration of $174.1 million . (4) Net of amortization of $10.0 million and $9.0 million at March 31, 2017 and December 31, 2016 , respectively.

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2017
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Income taxes included in the consolidated financial statements were as follows for the periods presented (in millions): Three Months Ended 2017 2016 ENLC income tax expense $ 3.0 $ 0.2 Total income tax expense $ 3.0 $ 0.2
Reconciliation of Total Income Tax Expense to Income before Income Taxes	The following schedule reconciles total income tax expense and the amount calculated by applying the statutory U.S. federal tax rate to income before income taxes (in millions): Three Months Ended 2017 2016 Tax expense (benefit) at statutory federal rate (35%) $ 0.4 $ (160.5 ) State income taxes benefit, net of federal tax benefit — (14.9 ) Income tax expense from partnership 0.5 1.0 Unit-based compensation (1) 2.3 — Non-deductible expense related to asset impairment — 173.9 Other (0.2 ) 0.7 Total income tax expense $ 3.0 $ 0.2 (1) Relates to tax deficiencies recorded on vested units, which are recognized on the income statement in accordance with the adoption of ASU 2016-09.

Certain Provisions of the Par32

Certain Provisions of the Partnership Agreement (Tables)	3 Months Ended
	Mar. 31, 2017
Partners' Capital [Abstract]
Distributions Made to Limited Partner, by Distribution	A summary of ENLK’s distribution activity relating to the common units for the three months ended March 31, 2017 and 2016 , respectively, is provided below: Declaration period Distribution/unit Date paid/payable 2017 Fourth Quarter of 2016 $ 0.39 February 13, 2017 First Quarter of 2017 $ 0.39 May 12, 2017 2016 Fourth Quarter of 2015 $ 0.39 February 11, 2016 First Quarter of 2016 $ 0.39 May 12, 2016
Schedule of Incentive Distributions Made to Managing Members or General Partners by Distribution	Net income is allocated to the General Partner in an amount equal to its incentive distribution rights as described in (b) above. The General Partner’s share of net income consists of incentive distribution rights to the extent earned, a deduction for unit-based compensation attributable to ENLC’s restricted units, the percentage interest of ENLK’s net income adjusted for ENLC’s unit-based compensation specifically allocated to our General Partner. The net income allocated to the General Partner is as follows (in millions): Three Months Ended 2017 2016 Income allocation for incentive distributions $ 14.7 $ 13.8 Unit-based compensation attributable to ENLC’s restricted units (8.8 ) (4.0 ) General Partner share of net income (loss) — (2.4 ) General Partner interest in net income $ 5.9 $ 7.4

Earnings Per Unit and Dilutio33

Earnings Per Unit and Dilution Computations (Tables)	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Computation of Basic and Diluted Earnings per Limited Partner Unit	As required under ASC 260, Earnings Per Share , unvested share-based payments that entitle employees to receive non-forfeitable distributions are considered participating securities for earnings per unit calculations. The following table reflects the computation of basic and diluted earnings per limited partner units for the periods presented (in millions, except per unit amounts): Three Months Ended March 31, 2017 2016 EnLink Midstream, LLC interest in net loss $ (1.9 ) $ (457.6 ) Distributed earnings allocated to: Common units (1) $ 45.9 $ 45.6 Unvested restricted units (1) 0.6 0.5 Total distributed earnings $ 46.5 $ 46.1 Undistributed loss allocated to: Common units $ (47.8 ) $ (498.5 ) Unvested restricted units (0.6 ) (5.2 ) Total undistributed loss $ (48.4 ) $ (503.7 ) Net loss allocated to: Common units $ (1.9 ) $ (452.9 ) Unvested restricted units — (4.7 ) Total net loss $ (1.9 ) $ (457.6 ) Basic and diluted net loss per unit: Basic $ (0.01 ) $ (2.56 ) Diluted $ (0.01 ) $ (2.56 ) (1) For the three months ended March 31, 2017 and 2016 , represents a declared distribution of $0.255 per unit payable May 15, 2017 and a declared distribution of $0.255 per unit payable May 13, 2016, respectively.
Summary of Distribution Activity	A summary of our distribution activity relating to the ENLC common units for the three months ended March 31, 2017 and 2016 , respectively, is provided below: Declaration period Distribution/unit Date paid/payable 2017 Fourth Quarter of 2016 $ 0.255 February 14, 2017 First Quarter of 2017 $ 0.255 May 15, 2017 2016 Fourth Quarter of 2015 $ 0.255 February 12, 2016 First Quarter of 2016 $ 0.255 May 13, 2016
Schedule of Unit Amounts Used to Computer Earnings per Unit	The following are the unit amounts used to compute the basic and diluted earnings per unit for the periods presented (in millions): Three Months Ended March 31, 2017 2016 Basic and diluted earnings per unit: Weighted average common units outstanding 180.2 178.7 Diluted weighted average units outstanding: Weighted average basic common units outstanding 180.2 178.7 Dilutive effect of restricted incentive units issued — — Total weighted average diluted common units outstanding 180.2 178.7

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Summary of Changes in Asset Retirement Obligations	The schedule below summarizes the changes in our asset retirement obligations (in millions): Three Months Ended March 31, 2017 Balance, beginning of period $ 13.5 Accretion expense 0.2 Balance, end of period $ 13.7

Investment in Unconsolidated 35

Investment in Unconsolidated Affiliates (Tables)	3 Months Ended
	Mar. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Activity Related to Investment in Unconsolidated Affiliates	The following table shows the activity related to our investment in unconsolidated affiliates for the periods indicated (in millions): Gulf Coast Fractionators Howard Energy Partners Cedar Cove JV Total Three Months Ended March 31, 2017 Contributions $ — $ — $ 6.0 $ 6.0 Distributions $ 2.7 $ — $ 0.2 $ 2.9 Equity in income (loss) (1) $ 4.0 $ (3.4 ) $ 0.1 $ 0.7 March 31, 2016 Contributions $ — $ 7.1 $ — $ 7.1 Distributions $ 3.0 $ 6.2 $ — $ 9.2 Equity in loss $ (1.7 ) $ (0.7 ) $ — $ (2.4 ) (1) Includes a loss of $3.4 million for the three months ended March 31, 2017 from the sale of HEP in March 2017. The following table shows the balances related to our investment in unconsolidated affiliates as of March 31, 2017 and December 31, 2016 (in millions): March 31, 2017 December 31, 2016 Gulf Coast Fractionators $ 49.8 $ 48.5 Howard Energy Partners — 193.1 Cedar Cove JV 34.7 28.8 Total investment in unconsolidated affiliates $ 84.5 $ 270.4

Employee Incentive Plans (Table

Employee Incentive Plans (Tables)	3 Months Ended
	Mar. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Amounts Recognized in Consolidated Financial Statements	Amounts recognized in the consolidated financial statements with respect to these plans are as follows (in millions): Three Months Ended March 31, 2017 2016 Cost of unit-based compensation charged to general and administrative expense $ 14.4 $ 6.3 Cost of unit-based compensation charged to operating expense 5.0 1.7 Total unit-based compensation expense $ 19.4 $ 8.0 Interest of non-controlling partners in unit-based compensation $ 7.3 $ 2.9 Amount of related income tax expense recognized in net income $ 4.6 $ 1.9
Summary of Restricted Incentive Unit Activity	A summary of the restricted incentive unit activity for the three months ended March 31, 2017 is provided below: Three Months Ended EnLink Midstream, LLC Restricted Incentive Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 1,897,298 $ 19.96 Granted (1) 781,842 19.29 Vested (1)(2) (726,692 ) 28.07 Forfeited (6,706 ) 17.58 Non-vested, end of period 1,945,742 $ 16.67 Aggregate intrinsic value, end of period (in millions) $ 37.7 (1) Restricted incentive units were issued in the first quarter of 2017 to officers and other employees. These restricted incentive units typically vest at the end of three years. In March 2017, we issued 258,606 restricted incentive units with a fair value of $5.0 million to officers and certain employees as bonus payments for 2016, and these restricted incentive units vested immediately and are included in the restricted incentive units granted and vested line items. (2) Vested units include 224,709 units withheld for payroll taxes paid on behalf of employees. ENLK restricted incentive units are valued at their fair value at the date of grant, which is equal to the market value of common units on such date. A summary of the restricted incentive unit activity for the three months ended March 31, 2017 is provided below: Three Months Ended EnLink Midstream Partners, LP Restricted Incentive Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 2,024,820 $ 19.05 Granted (1) 822,865 18.46 Vested (1)(2) (795,188 ) 25.84 Forfeited (6,997 ) 16.87 Non-vested, end of period 2,045,500 $ 16.18 Aggregate intrinsic value, end of period (in millions) $ 37.4 (1) Restricted incentive units were issued in the first quarter of 2017 to officers and other employees. These restricted incentive units typically vest at the end of three years. In March 2017, ENLK issued 262,288 restricted incentive units with a fair value of $5.1 million to officers and certain employees as bonus payments for 2016, and these restricted incentive units vested immediately and are included in the restricted incentive units granted and vested line items. (2) Vested units include 258,145 units withheld for payroll taxes paid on behalf of employees.
Summary of Restricted Units' Aggregate Intrinsic Value	A summary of the restricted incentive units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) for the three months ended March 31, 2017 and 2016 , respectively, are provided below (in millions): Three Months Ended March 31, EnLink Midstream LLC Restricted Incentive Units: 2017 2016 Aggregate intrinsic value of units vested $ 14.3 $ 3.8 Fair value of units vested $ 20.4 $ 11.8 A summary of the restricted incentive units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) for the three months ended March 31, 2017 and 2016 , respectively, is provided below (in millions): Three Months Ended March 31, EnLink Midstream Partners, LP Restricted Incentive Units: 2017 2016 Aggregate intrinsic value of units vested $ 15.3 $ 3.7 Fair value of units vested $ 20.5 $ 9.0
Summary of Grant-Date Fair Values	The following table presents a summary of the grant-date fair values of performance units granted and the related assumptions: EnLink Midstream Partners, LP Performance Units: March 2017 Beginning TSR Price $ 17.55 Risk-free interest rate 1.62 % Volatility factor 43.94 % Distribution yield 8.7 % The following table presents a summary of the grant-date fair values of performance units granted and the related assumptions: EnLink Midstream, LLC Performance Units: March 2017 Beginning TSR Price $ 18.29 Risk-free interest rate 1.62 % Volatility factor 52.07 % Distribution yield 5.4 %
Summary of Performance Units	The following table presents a summary of the performance units: Three Months Ended EnLink Midstream, LLC Performance Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 384,264 $ 19.30 Granted 164,575 28.77 Forfeited — — Non-vested, end of period 548,839 $ 22.14 Aggregate intrinsic value, end of period (in millions) $ 10.6 The following table presents a summary of the performance units: Three Months Ended EnLink Midstream Partners, LP Performance Units: Number of Units Weighted Average Grant-Date Fair Value Non-vested, beginning of period 408,637 $ 11.53 Granted 176,648 25.73 Forfeited — — Non-vested, end of period 585,285 $ 15.82 Aggregate intrinsic value, end of period (in millions) $ 10.7

Derivatives (Tables)

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Components of Gain (Loss) on Derivative Activity	The components of gain (loss) on derivative activity in the consolidated statements of operations related to commodity swaps are (in millions): Three Months Ended March 31, 2017 2016 Change in fair value of derivatives $ 5.3 $ (6.0 ) Realized gain (loss) on derivatives (2.5 ) 5.6 Gain (loss) on derivative activity $ 2.8 $ (0.4 )
Fair Value of Derivative Assets and Liabilities Related to Commodity Swaps	The fair value of derivative assets and liabilities related to commodity swaps are as follows (in millions): March 31, 2017 December 31, 2016 Fair value of derivative assets — current $ 2.1 $ 1.3 Fair value of derivative assets — long-term 0.1 — Fair value of derivative liabilities — current (2.9 ) (7.6 ) Fair value of derivative liabilities — long-term (0.3 ) — Net fair value of derivatives $ (1.0 ) $ (6.3 )
Notional Amount and Fair Value of Derivative Instruments	Set forth below is the summarized notional volumes and fair values of all instruments held for price risk management purposes and related physical offsets at March 31, 2017 (in millions). The remaining term of the contracts extend no later than October 2018. March 31, 2017 Commodity Instruments Unit Volume Fair Value NGL (short contracts) Swaps Gallons (32.9 ) $ (0.3 ) NGL (long contracts) Swaps Gallons 12.8 (0.2 ) Natural Gas (short contracts) Swaps MMBtu (15.4 ) (0.3 ) Natural Gas (long contracts) Swaps MMBtu 15.1 (0.4 ) Condensate (short contracts) Swaps MMbbls — 0.1 Condensate (long contracts) Swaps MMbbls — 0.1 Total fair value of derivatives $ (1.0 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2017
Fair Value Disclosures [Abstract]
Schedule of Net Assets (Liabilities) Measured on a Recurring Basis	Net assets (liabilities) measured at fair value on a recurring basis are summarized below (in millions): Level 2 March 31, 2017 December 31, 2016 Commodity Swaps (1) $ (1.0 ) $ (6.3 ) Total $ (1.0 ) $ (6.3 ) (1) The fair values of derivative contracts included in assets or liabilities for risk management activities represent the amount at which the instruments could be exchanged in a current arms-length transaction adjusted for our credit risk and/or the counterparty credit risk as required under ASC 820.
Schedule of the Estimated Fair Value of Financial Instruments	The estimated fair value of our financial instruments has been determined using available market information and valuation methodologies. Considerable judgment is required to develop the estimates of fair value; thus, the estimates provided below are not necessarily indicative of the amount we could realize upon the sale or refinancing of such financial instruments (in millions): March 31, 2017 December 31, 2016 Carrying Value Fair Value Carrying Value Fair Value Long-term debt (1) $ 3,521.1 $ 3,543.1 $ 3,295.8 $ 3,253.6 Installment Payables $ 230.1 $ 232.9 $ 473.2 $ 476.6 Obligations under capital lease $ 5.1 $ 4.3 $ 6.6 $ 6.1 (1) The carrying values of long-term debt are reduced by debt issuance costs of $23.8 million and $24.6 million at March 31, 2017 and December 31, 2016 , respectively. The respective fair values do not factor in debt issuance costs.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Summary of Financial Information	Summarized financial information for our reportable segments is shown in the following table (in millions): Texas Louisiana Oklahoma Crude and Condensate Corporate Totals Three Months Ended March 31, 2017 Product sales $ 85.1 $ 544.5 $ 14.5 $ 345.9 $ — $ 990.0 Product sales—related parties 106.5 10.2 64.4 0.8 (139.2 ) 42.7 Midstream services 27.8 53.1 27.9 18.6 — 127.4 Midstream services—related parties 105.1 29.0 49.4 3.3 (27.8 ) 159.0 Cost of sales (179.2 ) (564.7 ) (88.7 ) (336.7 ) 167.0 (1,002.3 ) Operating expenses (43.9 ) (25.4 ) (14.1 ) (20.7 ) — (104.1 ) Gain on derivative activity — — — — 2.8 2.8 Segment profit $ 101.4 $ 46.7 $ 53.4 $ 11.2 $ 2.8 $ 215.5 Depreciation and amortization $ (49.8 ) $ (28.1 ) $ (36.5 ) $ (11.5 ) $ (2.4 ) $ (128.3 ) Goodwill $ 232.0 $ — $ 190.3 $ — $ 1,119.9 $ 1,542.2 Capital expenditures $ 28.3 $ 32.7 $ 140.7 $ 37.4 $ 9.0 $ 248.1 Three Months Ended March 31, 2016 Product sales $ 62.5 $ 287.7 $ 7.8 $ 230.5 $ — $ 588.5 Product sales—related parties 37.3 7.4 10.6 0.2 (31.0 ) 24.5 Midstream services 27.4 55.2 15.1 16.8 — 114.5 Midstream services—related parties 110.3 12.7 45.0 5.2 (10.6 ) 162.6 Cost of sales (91.3 ) (302.1 ) (19.3 ) (215.1 ) 41.6 (586.2 ) Operating expenses (39.3 ) (23.3 ) (12.8 ) (22.8 ) — (98.2 ) Loss on derivative activity — — — — (0.4 ) (0.4 ) Segment profit (loss) $ 106.9 $ 37.6 $ 46.4 $ 14.8 $ (0.4 ) $ 205.3 Depreciation and amortization $ (46.2 ) $ (29.3 ) $ (33.8 ) $ (10.4 ) $ (2.2 ) $ (121.9 ) Impairments $ (473.1 ) $ — $ — $ (93.2 ) $ (307.0 ) $ (873.3 ) Goodwill $ 230.4 $ — $ 190.3 $ — $ 1,119.9 $ 1,540.6 Capital expenditures $ 23.3 $ 22.7 $ 69.2 $ 3.3 $ 1.9 $ 120.4
Schedule of Segment Assets	The table below represents information about segment assets as of March 31, 2017 and December 31, 2016 (in millions): Segment Identifiable Assets: March 31, 2017 December 31, 2016 Texas $ 3,132.6 $ 3,142.6 Louisiana 2,312.7 2,349.3 Oklahoma 2,629.8 2,524.5 Crude and Condensate 861.9 836.8 Corporate 1,240.5 1,422.7 Total identifiable assets $ 10,177.5 $ 10,275.9
Reconciliation of Profits to Operating Income (Loss)	The following table reconciles the segment profits reported above to the operating income (loss) as reported in the consolidated statements of operations (in millions): Three Months Ended March 31, 2017 2016 Segment profits $ 215.5 $ 205.3 General and administrative expenses (36.1 ) (35.1 ) Gain (loss) on disposition of assets (5.1 ) 0.2 Depreciation and amortization (128.3 ) (121.9 ) Impairments (7.0 ) (873.3 ) Gain on litigation settlement 17.5 $ — Operating income (loss) $ 56.5 $ (824.8 )

Supplemental Cash Flow Inform40

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Summary of Non-Cash Financing Activities	The following schedule summarizes non-cash financing activities for the periods presented (in millions): Three Months Ended March 31, 2017 2016 Non-cash financing activities: Non-cash issuance of ENLC common units (1) $ — $ 214.9 Installment payable, net of discount of $79.1 million (2) — 420.9 (1) Non-cash ENLC common units were issued as partial consideration for the acquisition of EnLink Oklahoma T.O. assets. See “ Note 3—Acquisition ” for further discussion. (2) ENLK incurred installment purchase obligations, net of discount, payable to the seller in connection with the EnLink Oklahoma T.O. assets. ENLK paid the first installment on January 6, 2017 and will pay the final installment no later than January 7, 2018. See “ Note 3—Acquisition ” for further discussion.

Other Information (Tables)

Other Information (Tables)	3 Months Ended
	Mar. 31, 2017
Other Liabilities Disclosure [Abstract]
Schedule of Other Current Liabilities	The following table presents additional detail for other current liabilities, which consists of the following (in millions): March 31, 2017 December 31, 2016 Accrued interest $ 58.4 $ 34.2 Accrued wages and benefits, including taxes 9.2 19.0 Accrued ad valorem taxes 13.0 23.5 Capital expenditure accruals 56.3 64.6 Onerous performance obligations 15.8 15.9 Other 61.6 60.3 Other current liabilities $ 214.3 $ 217.5

General (Details)

General (Details)	3 Months Ended
	Mar. 31, 2017shares
EnLink Midstream Partners, LP
Related Party Transaction [Line Items]
Units owned, limited partner interest (in shares)	88,528,451
Ownership interest	22.00%
Membership interest in the General Partner	0.40%
EnLink Midstream Partners GP, LLC
Related Party Transaction [Line Items]
Ownership interest	100.00%
EnLink Oklahoma T.O.
Related Party Transaction [Line Items]
Ownership interest	16.00%

Significant Accounting Polici43

Significant Accounting Policies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Property, Plant and Equipment [Line Items]
Gain (loss) on disposition of assets	$ (5.1)	$ 0.2
Recognized impairments	7	$ 873.3
Permian Basin
Property, Plant and Equipment [Line Items]
Gain (loss) on disposition of assets	$ (5.1)

Acquisitions - Narrative (Detai

Acquisitions - Narrative (Details) - USD ($) $ in Millions	Jan. 06, 2017	Jan. 07, 2016	Mar. 31, 2016	Mar. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Common units issued (in shares)				180,551,299	180,049,316
EnLink Oklahoma T.O.
Business Acquisition [Line Items]
Acquired voting interest		16.00%
Consideration		$ 1,441.6
First installment		1,020
Payment of second installment	$ 250
Final installment payable		250
Cash		$ 805.8
Common units issued (in shares)		15,564,009
Cash		$ 22.2
Estimated life of acquired intangible assets		15 years
Transaction costs		$ 4.8	$ 4.3
Recognized revenue			27.3
Net gain (loss) related to assets acquired			$ (14.2)
EnLink Oklahoma T.O. | EnLink Midstream Partners, LP
Business Acquisition [Line Items]
Acquired voting interest		84.00%
Cash		$ 783.6

Acquisitions - Schedule of Cons

Acquisitions - Schedule of Consideration, Assets and Liabilities (Details) - EnLink Oklahoma T.O. $ in Millions	Jan. 07, 2016USD ($)
Business Combination, Consideration Transferred [Abstract]
Cash	$ 805.8
Issuance of common units	214.9
Total consideration	1,441.6
Assets acquired:
Current assets (including $12.8 million in cash)	23
Cash acquired	12.8
Property, plant and equipment	406.1
Intangibles	1,051.3
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities [Abstract]
Current liabilities	(38.8)
Total identifiable net assets	1,441.6
EnLink Midstream LP
Business Combination, Consideration Transferred [Abstract]
ENLK’s total installment payable, net of discount of $79.1 million assuming payments made on January 7, 2017 and 2018	420.9
Installment payable discount	$ 79.1

Goodwill and Intangible Asset46

Goodwill and Intangible Assets - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Goodwill impairment loss recognized		$ 873.3
Amortization expense	$ 29.5	$ 27.5
Minimum
Finite-Lived Intangible Assets [Line Items]
Estimated useful life of intangible assets	10 years
Maximum
Finite-Lived Intangible Assets [Line Items]
Estimated useful life of intangible assets	20 years
Weighted average
Finite-Lived Intangible Assets [Line Items]
Estimated useful life of intangible assets	13 years 8 months

Goodwill and Intangible Asset47

Goodwill and Intangible Assets - Changes in Carrying Value (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Finite-lived Intangible Assets [Roll Forward]
Accumulated Amortization, Beginning Balance	$ (171.6)
Accumulated Amortization, Amortization expense	(29.5)	$ (27.5)
Accumulated Amortization, Ending Balance	(201.1)
EnLink Midstream Partners, LP
Finite-lived Intangible Assets [Roll Forward]
Net Carrying Amount, Ending Balance	1,594.7
Customer relationships | EnLink Midstream Partners, LP
Finite-lived Intangible Assets [Roll Forward]
Gross Carrying Amount, Beginning Balance	1,795.8
Accumulated Amortization, Beginning Balance	(171.6)
Net Carrying Amount, Beginning Balance	1,624.2
Accumulated Amortization, Amortization expense	(29.5)
Gross Carrying Amount, Ending Balance	1,795.8
Accumulated Amortization, Ending Balance	(201.1)
Net Carrying Amount, Ending Balance	$ 1,594.7

Goodwill and Intangible Asset48

Goodwill and Intangible Assets - Amortization Expense (Details) - EnLink Midstream Partners, LP $ in Millions	Mar. 31, 2017USD ($)
Finite-Lived Intangible Assets [Line Items]
2017 (remaining)	$ 88.4
2,018	117.9
2,019	117.9
2,020	117.9
2,021	117.9
Thereafter	1,034.7
Total	$ 1,594.7

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Related Party Transaction [Line Items]
Accounts payable to related party	$ 12.5		$ 10.4
Devon Energy Corporation
Related Party Transaction [Line Items]
Accounts receivable balance	106.9		100.2
Accounts payable to related party	$ 11.8		$ 10.4
Devon Energy Corporation | Customer Concentration Risk | Sales Revenue, Net
Related Party Transaction [Line Items]
Concentration risk	14.90%	21.00%

Long-Term Debt - Summary (Detai

Long-Term Debt - Summary (Details) - USD ($) $ in Millions	Jun. 01, 2017	Apr. 03, 2017	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument
Outstanding Principal			$ 3,536	$ 3,310.3
Premium (Discount)			8.9	9.6
Long-Term Debt			3,544.9	3,319.9
Debt issuance costs			(23.8)	(24.6)
Long-term debt, net of unamortized issuance cost			$ 3,521.1	$ 3,295.3
Effective interest rate			3.00%	2.30%
Debt issuance cost accumulated amortization			$ 10	$ 9
ENLK credit facility due 2020 | EnLink Midstream Partners, LP
Debt Instrument
Outstanding Principal			330	120
Premium (Discount)			0	0
Long-Term Debt			330	120
ENLC credit facility due 2019
Debt Instrument
Outstanding Principal			43.5	27.8
Premium (Discount)			0	0
Long-Term Debt			$ 43.5	$ 27.8
Effective interest rate			3.10%	3.40%
2.70% Senior unsecured notes due 2019
Debt Instrument
Stated interest rate			2.70%
Outstanding Principal			$ 400	$ 400
Premium (Discount)			(0.2)	(0.3)
Long-Term Debt			$ 399.8	399.7
7.125% Senior unsecured notes due 2022
Debt Instrument
Stated interest rate			7.125%
Outstanding Principal			$ 162.5	162.5
Premium (Discount)			15.2	16
Long-Term Debt			$ 177.7	178.5
4.40% Senior unsecured notes due 2024
Debt Instrument
Stated interest rate			4.40%
Outstanding Principal			$ 550	550
Premium (Discount)			2.4	2.5
Long-Term Debt			$ 552.4	552.5
4.15% Senior unsecured notes due 2025
Debt Instrument
Stated interest rate			4.15%
Outstanding Principal			$ 750	750
Premium (Discount)			(1.1)	(1.1)
Long-Term Debt			$ 748.9	748.9
4.85% Senior unsecured notes due 2026 | EnLink Midstream Partners, LP
Debt Instrument
Stated interest rate			4.85%
Outstanding Principal			$ 500	500
Premium (Discount)			(0.6)	(0.7)
Long-Term Debt			$ 499.4	499.3
5.60% Senior unsecured notes due 2044
Debt Instrument
Stated interest rate			5.60%
Outstanding Principal			$ 350	350
Premium (Discount)			(0.2)	(0.2)
Long-Term Debt			$ 349.8	349.8
5.05% Senior unsecured notes due 2045
Debt Instrument
Stated interest rate			5.05%
Outstanding Principal			$ 450	450
Premium (Discount)			(6.6)	(6.6)
Long-Term Debt			$ 443.4	$ 443.4
Senior notes | Unsecured, 2022 Notes | Forecast
Debt Instrument
Redemption price as a percentage of the principal amount	103.60%
Redemption price plus accrued interest	$ 174.1
Senior notes | Unsecured, 2022 Notes | Subsequent event
Debt Instrument
Stated interest rate		7.125%

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details)	3 Months Ended
	Mar. 31, 2017USD ($)extensionsubsidiaryshares	Dec. 31, 2016USD ($)
Debt Instrument
Outstanding borrowings	$ 330,000,000
Amount available for future borrowings	1,200,000,000
ENLC credit facility due 2019
Debt Instrument
Maximum borrowing capacity	$ 250,000,000
Units owned, limited partner interest (in shares) | shares	88,528,451
Membership interest in the General Partner	100.00%
Ownership interest	100.00%
Maximum consolidated leverage ratio	0.045
Outstanding borrowings	$ 43,500,000	$ 27,800,000
Amount available for future borrowings	$ 206,500,000
ENLC credit facility due 2019 | Maximum
Debt Instrument
Ratio of consolidated indebtedness to consolidated EBITDA	0.04
ENLC credit facility due 2019 | Minimum
Debt Instrument
Ratio of consolidated indebtedness to consolidated EBITDA	0.025
ENLC credit facility due 2019 | Letter of Credit
Debt Instrument
Maximum borrowing capacity	$ 125,000,000
Number of wholly-owned subsidiaries that are used as the guarantee | subsidiary	2
ENLC credit facility due 2019 | LIBOR | Maximum
Debt Instrument
Variable rate	2.50%
ENLC credit facility due 2019 | LIBOR | Minimum
Debt Instrument
Variable rate	1.75%
ENLC credit facility due 2019 | Federal Funds
Debt Instrument
Variable rate	0.50%
ENLC credit facility due 2019 | Eurodollar
Debt Instrument
Variable rate	1.00%
ENLC credit facility due 2019 | Eurodollar | Maximum
Debt Instrument
Variable rate	1.50%
ENLC credit facility due 2019 | Eurodollar | Minimum
Debt Instrument
Variable rate	0.75%
ENLK credit facility due 2020 | EnLink Midstream Partners, LP
Debt Instrument
Maximum borrowing capacity	$ 1,500,000,000
Ratio of consolidated indebtedness to consolidated EBITDA	0.05
Outstanding borrowings	$ 330,000,000	$ 120,000,000
Additional amount available (not to exceed)	$ 500,000,000
Number of allowed extensions | extension	2
Extension period	1 year
Conditional acquisition purchase price (or more)	$ 50,000,000
ENLK credit facility due 2020 | Maximum | EnLink Midstream Partners, LP
Debt Instrument
Ratio of consolidated indebtedness to consolidated EBITDA	0.055
ENLK credit facility due 2020 | Letter of Credit | EnLink Midstream Partners, LP
Debt Instrument
Outstanding letters of credit	$ 9,100,000
ENLK credit facility due 2020 | LIBOR | Maximum | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	1.75%
ENLK credit facility due 2020 | LIBOR | Minimum | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	1.00%
ENLK credit facility due 2020 | Federal Funds | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	0.50%
ENLK credit facility due 2020 | Eurodollar | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	1.00%
ENLK credit facility due 2020 | Eurodollar | Maximum | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	0.75%
ENLK credit facility due 2020 | Eurodollar | Minimum | EnLink Midstream Partners, LP
Debt Instrument
Variable rate	0.00%

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Total income tax expense	$ 3	$ 0.2
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Tax expense (benefit) at statutory federal rate (35%)	$ 0.4	(160.5)
Federal statutory tax rate	35.00%
State income taxes benefit, net of federal tax benefit	$ 0	(14.9)
Income tax expense from partnership	0.5	1
Unit-based compensation	2.3	0
Non-deductible expense related to asset impairment	0	173.9
Other	(0.2)	0.7
Total income tax expense	$ 3	$ 0.2

Certain Provisions of the Par53

Certain Provisions of the Partnership Agreement - Narrative and Distributions (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015	Nov. 30, 2014
Partnership agreement
Proceeds from sale of common units	$ 55.2		$ 2.1
Distributions of Preferred Units paid-in kind (in shares)		1,130,131
Preferred Units
Partnership agreement
Distribution of Preferred Units declared (in shares)	1,154,147
EnLink Midstream Partners, LP
Partnership agreement
Percentage of available cash to distribute	100.00%
Period after quarter for distribution	45 days
EnLink Midstream Partners, LP | Common units
Partnership agreement
Distribution/unit (in dollars per share)	$ 0.39	$ 0.39	$ 0.39	$ 0.39
EnLink Midstream Partners, LP | General Partner | Incentive Distribution Level 1
Partnership agreement
Incentive distribution for general partner	13.00%
Incentive distribution, conditional distribution per unit (in dollars per share)	$ 0.25
EnLink Midstream Partners, LP | General Partner | Incentive Distribution Level 2
Partnership agreement
Incentive distribution for general partner	23.00%
Incentive distribution, conditional distribution per unit (in dollars per share)	$ 0.3125
EnLink Midstream Partners, LP | General Partner | Incentive Distribution Level 3
Partnership agreement
Incentive distribution for general partner	48.00%
Incentive distribution, conditional distribution per unit (in dollars per share)	$ 0.375
EnLink Midstream Partners, LP | BMO EDA
Partnership agreement
Agreement for gross sales of common units (up to)					$ 350
Common units sold	$ 3
Proceeds from sale of common units	55.2
Commissions	0.6
Gross common unit issuances available	$ 92

Certain Provisions of the Par54

Certain Provisions of the Partnership Agreement - Allocation of Income (Details) - General Partner - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Incentive distribution
Income allocation for incentive distributions	$ 14.7	$ 13.8
Unit-based compensation attributable to ENLC’s restricted units	(8.8)	(4)
General Partner share of net income (loss)	0	(2.4)
General Partner interest in net income	$ 5.9	$ 7.4

Earnings Per Unit and Dilutio55

Earnings Per Unit and Dilution Computations - Computation and Distribution Activity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
EnLink Midstream, LLC interest in net loss	$ (1.9)		$ (457.6)
Distributed earnings allocated to:
Total distributed earnings	46.5		46.1
Undistributed loss allocated to:
Total undistributed loss	(48.4)		(503.7)
Net loss allocated to:
Total net loss	$ (1.9)		$ (457.6)
Basic and diluted net loss per unit:
Basic (in dollars per share)	$ (0.01)		$ (2.56)
Diluted common unit (in dollars per share)	(0.01)		(2.56)
Declared distribution (in dollars per share)	$ 0.255	$ 0.255	$ 0.255	$ 0.255
Unvested restricted units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
EnLink Midstream, LLC interest in net loss	$ 0		$ (4.7)
Distributed earnings allocated to:
Total distributed earnings	0.6		0.5
Undistributed loss allocated to:
Total undistributed loss	(0.6)		(5.2)
Net loss allocated to:
Total net loss	0		(4.7)
Common units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
EnLink Midstream, LLC interest in net loss	(1.9)		(452.9)
Distributed earnings allocated to:
Total distributed earnings	45.9		45.6
Undistributed loss allocated to:
Total undistributed loss	(47.8)		(498.5)
Net loss allocated to:
Total net loss	$ (1.9)		$ (452.9)

Earnings Per Unit and Dilutio56

Earnings Per Unit and Dilution Computations - Components to Computer Basic and Diluted Earnings per Unit (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Basic and diluted net loss per unit:
Weighted average common units outstanding (in shares)	180.2	178.7
Diluted weighted average units outstanding:
Weighted average basic common units outstanding (in shares)	180.2	178.7
Dilutive effect of restricted incentive units issued (in shares)	0	0
Total weighted average diluted common units outstanding (in shares)	180.2	178.7

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)
Asset retirement obligation
Beginning balance	$ 13.5
Accretion expense	0.2
Ending balance	$ 13.7

Investment in Unconsolidated 58

Investment in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Equity method investments
Proceeds from sale of unconsolidated affiliate investment	$ 189.7	$ 0.2
Contributions	6	7.1
Equity in income (loss)	0.7	(2.4)
Total investment in unconsolidated affiliates	$ 84.5		$ 77.3
Gulf Coast Fractionators
Equity method investments
Ownership interest	38.75%		38.75%
Howard Energy Partners
Equity method investments
Ownership interest			31.00%
Proceeds from sale of unconsolidated affiliate investment	$ 189.7
Cedar Cove JV
Equity method investments
Ownership interest	30.00%		30.00%
EnLink Midstream Partners, LP
Equity method investments
Contributions	$ 6	7.1
Distributions	2.9	9.2
Equity in income (loss)	0.7	(2.4)
Total investment in unconsolidated affiliates	84.5		$ 270.4
EnLink Midstream Partners, LP | Gulf Coast Fractionators
Equity method investments
Contributions	0	0
Distributions	2.7	3
Equity in income (loss)	4	(1.7)
Total investment in unconsolidated affiliates	49.8		48.5
EnLink Midstream Partners, LP | Howard Energy Partners
Equity method investments
Contributions	0	7.1
Distributions	0	6.2
Equity in income (loss)	(3.4)	(0.7)
Total investment in unconsolidated affiliates	0		193.1
EnLink Midstream Partners, LP | Cedar Cove JV
Equity method investments
Contributions	6	0
Distributions	0.2	0
Equity in income (loss)	0.1	$ 0
Total investment in unconsolidated affiliates	$ 34.7		$ 28.8

Employee Incentive Plans - Amou

Employee Incentive Plans - Amounts Recognized in Consolidated Financial Statements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Allocation
Compensation expense	$ 19.4	$ 8
Amount of related income tax expense recognized in net income	4.6	1.9
Cost of unit-based compensation charged to general and administrative expense
Allocation
Compensation expense	14.4	6.3
Cost of unit-based compensation charged to operating expense
Allocation
Compensation expense	5	1.7
Interest of non-controlling partners in unit-based compensation
Allocation
Compensation expense	$ 7.3	$ 2.9

Employee Incentive Plans - Rest

Employee Incentive Plans - Restricted and Performance Awards (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2017	Mar. 31, 2016
Restricted incentive units
Number of Units
Non-vested, beginning of period (in shares)		1,897,298
Granted (in shares)		781,842
Vested (in shares)	(258,606)	(726,692)
Forfeited (in shares)		(6,706)
Non-vested, end of period (in shares)	1,945,742	1,945,742
Aggregate intrinsic value, end of period	$ 37.7	$ 37.7
Weighted Average Grant-Date Fair Value
Non-vested, beginning of period (in dollars per share)		$ 19.96
Granted (in dollars per share)		19.29
Vested (in dollars per share)		28.07
Forfeited (in dollars per share)		17.58
Non-vested, end of period (in dollars per share)	$ 16.67	$ 16.67
Fair value of units vested	$ 5	$ 20.4	$ 11.8
Units withheld for payroll taxes (in shares)		224,709
Aggregate intrinsic value of units vested		$ 14.3	3.8
Unrecognized compensation cost related to non-vested restricted incentive units	$ 20.2	$ 20.2
Unrecognized compensation costs, weighted average period for recognition		2 years
Performance units
Number of Units
Non-vested, beginning of period (in shares)		384,264
Granted (in shares)		164,575
Forfeited (in shares)		0
Non-vested, end of period (in shares)	548,839	548,839
Aggregate intrinsic value, end of period	$ 10.6	$ 10.6
Weighted Average Grant-Date Fair Value
Non-vested, beginning of period (in dollars per share)		$ 19.30
Granted (in dollars per share)		28.77
Forfeited (in dollars per share)		0
Non-vested, end of period (in dollars per share)	$ 22.14	$ 22.14
Unrecognized compensation cost related to non-vested restricted incentive units	$ 8.1	$ 8.1
Unrecognized compensation costs, weighted average period for recognition		2 years 3 months
Vesting period		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Beginning TSR Price		$ 18.29
Risk-free interest rate		1.62%
Volatility factor		52.07%
Distribution yield		5.40%
Performance units | Minimum
Weighted Average Grant-Date Fair Value
Percent of units vesting		0.00%
Performance units | Maximum
Weighted Average Grant-Date Fair Value
Percent of units vesting		200.00%
EnLink Midstream Partners, LP | Restricted incentive units
Number of Units
Non-vested, beginning of period (in shares)		2,024,820
Granted (in shares)		822,865
Vested (in shares)	(262,288)	(795,188)
Forfeited (in shares)		(6,997)
Non-vested, end of period (in shares)	2,045,500	2,045,500
Aggregate intrinsic value, end of period	$ 37.4	$ 37.4
Weighted Average Grant-Date Fair Value
Non-vested, beginning of period (in dollars per share)		$ 19.05
Granted (in dollars per share)		18.46
Vested (in dollars per share)		25.84
Forfeited (in dollars per share)		16.87
Non-vested, end of period (in dollars per share)	$ 16.18	$ 16.18
Fair value of units vested	$ 5.1	$ 20.5	9
Units withheld for payroll taxes (in shares)		258,145
Aggregate intrinsic value of units vested		$ 15.3	$ 3.7
Unrecognized compensation cost related to non-vested restricted incentive units	$ 20.7	$ 20.7
Unrecognized compensation costs, weighted average period for recognition		2 years
EnLink Midstream Partners, LP | Performance units
Number of Units
Non-vested, beginning of period (in shares)		408,637
Granted (in shares)		176,648
Forfeited (in shares)		0
Non-vested, end of period (in shares)	585,285	585,285
Aggregate intrinsic value, end of period	$ 10.7	$ 10.7
Weighted Average Grant-Date Fair Value
Non-vested, beginning of period (in dollars per share)		$ 11.53
Granted (in dollars per share)		25.73
Forfeited (in dollars per share)		0
Non-vested, end of period (in dollars per share)	$ 15.82	$ 15.82
Unrecognized compensation cost related to non-vested restricted incentive units	$ 8	$ 8
Unrecognized compensation costs, weighted average period for recognition		2 years 3 months
Vesting period		3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Beginning TSR Price		$ 17.55
Risk-free interest rate		1.62%
Volatility factor		43.94%
Distribution yield		8.70%
EnLink Midstream Partners, LP | Performance units | Minimum
Weighted Average Grant-Date Fair Value
Percent of units vesting		0.00%
EnLink Midstream Partners, LP | Performance units | Maximum
Weighted Average Grant-Date Fair Value
Percent of units vesting		200.00%

Derivatives - Components of Gai

Derivatives - Components of Gain (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Derivatives
Gain (loss) on derivative activity	$ 2.8	$ (0.4)
EnLink Midstream Partners, LP | Commodity Swaps
Derivatives
Change in fair value of derivatives	5.3	(6)
Realized gain (loss) on derivatives	(2.5)	5.6
Gain (loss) on derivative activity	$ 2.8	$ (0.4)

Derivatives - Fair Value of Ass

Derivatives - Fair Value of Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivatives
Fair value of derivative assets — current	$ 2.1	$ 1.3
Fair value of derivative assets — long-term	0.1	0
Fair value of derivative liabilities — current	(2.9)	(7.6)
Fair value of derivative liabilities — long-term	(0.3)	0
EnLink Midstream Partners, LP
Derivatives
Fair value of derivative assets — current	2.1	1.3
Fair value of derivative assets — long-term	0.1	0
Fair value of derivative liabilities — current	(2.9)	(7.6)
Fair value of derivative liabilities — long-term	(0.3)	0
Net fair value of derivatives	$ (1)	$ (6.3)

Derivatives - Commodities (Deta

Derivatives - Commodities (Details) - EnLink Midstream Partners, LP gal in Millions, MMBbls in Millions, MMBTU in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)MMBTUMMBblsgal	Dec. 31, 2016USD ($)
Derivatives
Fair Value	$ (1)	$ (6.3)
Commodity
Derivatives
Fair Value	(1)
Maximum loss if counterparties fail to perform	2.2
Possible reduction in maximum loss if counterparties fail to perform	$ 0.4
Commodity | NGL | Short
Derivatives
Notional amount (in gallons and mmbls) | gal	32.9
Fair Value	$ (0.3)
Commodity | NGL | Long
Derivatives
Notional amount (in gallons and mmbls) | gal	12.8
Fair Value	$ (0.2)
Commodity | Natural Gas | Short
Derivatives
Notional amount (in mmbtu) | MMBTU	15.4
Fair Value	$ (0.3)
Commodity | Natural Gas | Long
Derivatives
Notional amount (in mmbtu) | MMBTU	15.1
Fair Value	$ (0.4)
Commodity | Condensate | Short
Derivatives
Notional amount (in gallons and mmbls) | MMBbls	0
Fair Value	$ 0.1
Commodity | Condensate | Long
Derivatives
Notional amount (in gallons and mmbls) | MMBbls	0
Fair Value	$ 0.1

Fair Value Measurements - Recur

Fair Value Measurements - Recurring (Details) - Level 2 - Recurring - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value
Fair Value	$ (1)	$ (6.3)
Commodity Swaps
Fair Value
Fair Value	$ (1)	$ (6.3)

Fair Value Measurements - Finan

Fair Value Measurements - Financial Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value
Debt issuance costs	$ 23.8	$ 24.6
Outstanding borrowings	330
ENLC credit facility due 2019
Fair Value
Outstanding borrowings	43.5	27.8
EnLink Midstream Partners, LP
Fair Value
Senior unsecured debt	$ 3,100	$ 3,100
EnLink Midstream Partners, LP | Minimum
Fair Value
Stated interest rate	2.70%	2.70%
EnLink Midstream Partners, LP | Maximum
Fair Value
Stated interest rate	7.10%	7.10%
EnLink Midstream Partners, LP | ENLK credit facility due 2020
Fair Value
Outstanding borrowings	$ 330	$ 120
EnLink Midstream Partners, LP | Carrying Value
Fair Value
Long-term debt	3,521.1	3,295.8
Installment Payables	230.1	473.2
Obligations under capital lease	5.1	6.6
EnLink Midstream Partners, LP | Fair Value
Fair Value
Long-term debt	3,543.1	3,253.6
Installment Payables	232.9	476.6
Obligations under capital lease	$ 4.3	$ 6.1

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	1 Months Ended			3 Months Ended
	Mar. 31, 2017USD ($)	Aug. 31, 2014USD ($)	Jul. 31, 2013defendant	Mar. 31, 2017USD ($)	Mar. 31, 2016USD ($)
Commitments and Contingencies
Gain on litigation settlement		$ 6.1		$ 17.5	$ 0
Additional settlement payment received	$ 17.5
Judicial ruling | Board of Commissioners for the Southeast Louisiana Flood Protection Authority for New Orleans
Commitments and Contingencies
Number of energy companies sued (in defendant) | defendant			100

Segment Information - Financial

Segment Information - Financial Information and Assets (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Segment Reporting
Product sales		$ 990	$ 588.5
Product sales—related parties		42.7	24.5
Midstream services		127.4	114.5
Midstream services—related parties		159	162.6
Cost of sales	[1]	(1,002.3)	(586.2)
Operating expenses	[2]	(104.1)	(98.2)
Gain (loss) on derivative activity		2.8	(0.4)
Segment profit		215.5	205.3
Depreciation and amortization		(128.3)	(121.9)
Impairments		(7)	(873.3)
Goodwill		1,542.2	1,540.6	$ 1,542.2
Capital expenditures		248.1	120.4
Total identifiable assets		10,177.5		10,275.9
Corporate
Segment Reporting
Product sales		0	0
Product sales—related parties		(139.2)	(31)
Midstream services		0	0
Midstream services—related parties		(27.8)	(10.6)
Cost of sales		167	41.6
Operating expenses		0	0
Gain (loss) on derivative activity		2.8	(0.4)
Segment profit		2.8	(0.4)
Depreciation and amortization		(2.4)	(2.2)
Impairments			(307)
Goodwill		1,119.9	1,119.9
Capital expenditures		9	1.9
Total identifiable assets		1,240.5		1,422.7
Texas | Operating Segments
Segment Reporting
Product sales		85.1	62.5
Product sales—related parties		106.5	37.3
Midstream services		27.8	27.4
Midstream services—related parties		105.1	110.3
Cost of sales		(179.2)	(91.3)
Operating expenses		(43.9)	(39.3)
Gain (loss) on derivative activity		0	0
Segment profit		101.4	106.9
Depreciation and amortization		(49.8)	(46.2)
Impairments			(473.1)
Goodwill		232	230.4
Capital expenditures		28.3	23.3
Total identifiable assets		3,132.6		3,142.6
Louisiana | Operating Segments
Segment Reporting
Product sales		544.5	287.7
Product sales—related parties		10.2	7.4
Midstream services		53.1	55.2
Midstream services—related parties		29	12.7
Cost of sales		(564.7)	(302.1)
Operating expenses		(25.4)	(23.3)
Gain (loss) on derivative activity		0	0
Segment profit		46.7	37.6
Depreciation and amortization		(28.1)	(29.3)
Impairments			0
Goodwill		0	0
Capital expenditures		32.7	22.7
Total identifiable assets		2,312.7		2,349.3
Oklahoma | Operating Segments
Segment Reporting
Product sales		14.5	7.8
Product sales—related parties		64.4	10.6
Midstream services		27.9	15.1
Midstream services—related parties		49.4	45
Cost of sales		(88.7)	(19.3)
Operating expenses		(14.1)	(12.8)
Gain (loss) on derivative activity		0	0
Segment profit		53.4	46.4
Depreciation and amortization		(36.5)	(33.8)
Impairments			0
Goodwill		190.3	190.3
Capital expenditures		140.7	69.2
Total identifiable assets		2,629.8		2,524.5
Crude and Condensate | Operating Segments
Segment Reporting
Product sales		345.9	230.5
Product sales—related parties		0.8	0.2
Midstream services		18.6	16.8
Midstream services—related parties		3.3	5.2
Cost of sales		(336.7)	(215.1)
Operating expenses		(20.7)	(22.8)
Gain (loss) on derivative activity		0	0
Segment profit		11.2	14.8
Depreciation and amortization		(11.5)	(10.4)
Impairments			(93.2)
Goodwill		0	0
Capital expenditures		37.4	$ 3.3
Total identifiable assets		$ 861.9		$ 836.8
[1]	Includes related party cost of sales of $28.7 million and $42.6 million for the three months ended March 31, 2017 and 2016, respectively.
[2]	Includes related party operating expenses of $0.2 million and $0.1 million for the three months ended March 31, 2017 and 2016, respectively.

Segment Information - Reconcili

Segment Information - Reconciliation (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Aug. 31, 2014	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting [Abstract]
Segment profits		$ 215.5	$ 205.3
General and administrative expenses		(36.1)	(35.1)
Gain (loss) on disposition of assets		(5.1)	0.2
Depreciation and amortization		(128.3)	(121.9)
Impairments		(7)	(873.3)
Gain on litigation settlement	$ 6.1	17.5	0
Operating income (loss)		$ 56.5	$ (824.8)

Supplemental Cash Flow Inform69

Supplemental Cash Flow Information (Details) - EnLink Oklahoma T.O. - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
EnLink Midstream Partners, LP
Noncash Transactions [Line Items]
Installment payable, net of discount of $79.1 million	$ 0	$ 420.9
Installment payable discount	79.1	79.1
Common Units
Noncash Transactions [Line Items]
Non-cash issuance of ENLC common units	$ 0	$ 214.9

Other Information (Details)

Other Information (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Other Liabilities Disclosure [Abstract]
Accrued interest	$ 58.4	$ 34.2
Accrued wages and benefits, including taxes	9.2	19
Accrued ad valorem taxes	13	23.5
Capital expenditure accruals	56.3	64.6
Onerous performance obligations	15.8	15.9
Other	61.6	60.3
Other current liabilities	$ 214.3	$ 217.5

Subsequent Event (Details)

Subsequent Event (Details) - Forecast - Senior notes - Unsecured, 2022 Notes - USD ($) $ in Millions	Jun. 01, 2017	Jun. 30, 2017
Subsequent Event [Line Items]
Redemption price as a percentage of the principal amount	103.60%
Redemption price plus accrued interest	$ 174.1
Gains on extinguishment of debt		$ 3.2