NGL Energy Partners (NGL) 8-K 19 Feb 20 Other Events Financial data

Document and Entity Information

Document and Entity Information Document	Feb. 19, 2020
Entity Information [Line Items]
Document Type	8-K
Document Period End Date	Feb. 19, 2020
Entity Registrant Name	NGL ENERGY PARTNERS LP
Entity Incorporation, State or Country Code	DE
Entity File Number	001-35172
Entity Tax Identification Number	27-3427920
Entity Address, Address Line One	6120 South Yale Avenue
Entity Address, Address Line Two	Suite 805
Entity Address, City or Town	Tulsa
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74136
City Area Code	918
Local Phone Number	481-1119
Written Communications	false
Soliciting Material	false
Pre-commencement Tender Offer	false
Pre-commencement Issuer Tender Offer	false
Entity Emerging Growth Company	false
Entity Central Index Key	0001504461
Amendment Flag	false
NEW YORK STOCK EXCHANGE, INC. | Common units
Entity Information [Line Items]
Title of 12(b) Security	Common units representing Limited Partner Interests
Trading Symbol	NGL
Security Exchange Name	NYSE
NEW YORK STOCK EXCHANGE, INC. | Class B Perpetual Preferred Units
Entity Information [Line Items]
Title of 12(b) Security	Fixed-to-floating rate cumulative redeemable perpetual preferred units
Trading Symbol	NGL-PB
Security Exchange Name	NYSE
NEW YORK STOCK EXCHANGE, INC. | Class C Perpetual Preferred Units
Entity Information [Line Items]
Title of 12(b) Security	Fixed-to-floating rate cumulative redeemable perpetual preferred units
Trading Symbol	NGL-PC
Security Exchange Name	NYSE

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2019	Mar. 31, 2018
CURRENT ASSETS:
Cash and cash equivalents	$ 18,572	$ 22,094
Accounts receivable-trade, net of allowance for doubtful accounts of $4,016 and $3,851, respectively	998,203	820,552
Accounts receivable-affiliates	12,867	4,772
Inventories	136,128	161,649
Prepaid expenses and other current assets	65,918	82,020
Assets held for sale	580,985	708,671
Total current assets	1,812,673	1,799,758
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $417,457 and $341,222, respectively	1,828,940	1,512,286
GOODWILL	1,110,456	1,170,530
INTANGIBLE ASSETS, net of accumulated amortization of $503,117 and $417,647, respectively	800,889	775,087
INVESTMENTS IN UNCONSOLIDATED ENTITIES	1,127	17,236
LOAN RECEIVABLE-AFFILIATE	0	1,200
OTHER NONCURRENT ASSETS	113,857	202,954
ASSETS HELD FOR SALE	234,551	672,071
Total assets	5,902,493	6,151,122
CURRENT LIABILITIES:
Accounts payable-trade	879,063	781,197
Accounts payable-affiliates	28,469	1,254
Accrued expenses and other payables	107,759	137,242
Advance payments received from customers	8,461	7,889
Current maturities of long-term debt	648	646
Liabilities held for sale	226,753	188,154
Total current liabilities	1,251,153	1,116,382
LONG-TERM DEBT, net of debt issuance costs of $12,008 and $20,645, respectively, and current maturities	2,160,133	2,679,740
OTHER NONCURRENT LIABILITIES	63,542	173,324
NONCURRENT LIABILITIES HELD FOR SALE	33	3,078
COMMITMENTS AND CONTINGENCIES (NOTE 9)
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS, 19,942,169 and 19,942,169 preferred units issued and outstanding, respectively	149,814	82,576
REDEEMABLE NONCONTROLLING INTEREST HELD FOR SALE	0	9,927
EQUITY:
General partner, representing a 0.1% interest, 124,633 and 121,594 notional units, respectively	(50,603)	(50,819)
Limited partners, representing a 99.9% interest, 124,508,497 and 121,472,725 common units issued and outstanding, respectively	2,067,197	1,852,495
Class B preferred limited partners, 8,400,000 and 8,400,000 preferred units issued and outstanding, respectively	202,731	202,731
Accumulated other comprehensive loss	(255)	(1,815)
Noncontrolling interests	58,748	83,503
Total equity	2,277,818	2,086,095
Total liabilities and equity	$ 5,902,493	$ 6,151,122

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Accounts receivable - trade, allowance for doubtful accounts	$ (4,016)	$ (3,851)
PROPERTY, PLANT AND EQUIPMENT, accumulated depreciation	417,457	341,222
INTANGIBLE ASSETS, accumulated amortization	503,117	417,647
Debt issuance costs, noncurrent, net	$ 12,008	$ 20,645
General partner interest	0.10%	0.10%
General partner, notional units outstanding (in units)	124,633	121,594
Limited partner interest	99.90%	99.90%
Limited partners, common units issued (in units)	124,508,497	121,472,725
Limited partners, common units outstanding (in units)	124,508,497	121,472,725
Class A Convertible Preferred Units
Preferred units dividend rate	10.75%	10.75%
Temporary equity, issued (in units)	19,942,169	19,942,169
Temporary equity, outstanding (in units)	19,942,169	19,942,169
Class B Perpetual Preferred Units
Preferred units, issued (in units)	8,400,000	8,400,000
Preferred units, outstanding (in units)	8,400,000	8,400,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
REVENUES:
Crude Oil Logistics	$ 3,136,635	$ 2,260,075	$ 1,666,884
Water Solutions	301,686	229,139	159,601
Liquids	2,415,041	2,215,985	1,537,172
Refined Products and Renewables	2,834,433	2,247,574	1,851,764
Other	1,362	1,174	844
Total Revenues	8,689,157	6,953,947	5,216,265
COST OF SALES:
Crude Oil Logistics	2,902,656	2,113,747	1,572,015
Water Solutions	(10,787)	19,345	4,068
Liquids	2,277,709	2,128,522	1,432,200
Refined Products and Renewables	2,811,554	2,001,417	1,729,880
Other	1,929	530	400
Total Cost of Sales	7,983,061	6,263,561	4,738,563
OPERATING COSTS AND EXPENSES:
Operating	231,065	193,076	173,046
General and administrative	107,407	97,979	100,839
Depreciation and amortization	211,973	208,398	179,613
Loss (gain) on disposal or impairment of assets, net	34,296	(17,118)	(208,982)
Revaluation of liabilities	(5,373)	20,716	6,717
Operating Income	126,728	187,335	226,469
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities	2,533	7,539	3,830
Revaluation of investments	0	0	(14,365)
Interest expense	(164,725)	(199,149)	(149,601)
(Loss) gain on early extinguishment of liabilities, net	(12,340)	(23,201)	24,727
Other (expense) income, net	(30,418)	6,352	26,420
(Loss) Income From Continuing Operations Before Income Taxes	(78,222)	(21,124)	117,480
INCOME TAX EXPENSE	(1,233)	(1,353)	(1,933)
(Loss) Income From Continuing Operations	(79,455)	(22,477)	115,547
Income (Loss) From Discontinued Operations, net of Tax	418,850	(47,128)	28,327
Net Income (Loss)	339,395	(69,605)	143,874
LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	20,206	(240)	(6,832)
LESS: NET LOSS (INCOME) ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS	446	(1,030)	0
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	360,047	(70,875)	137,042
NET (LOSS) INCOME FROM CONTINUING OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	(171,153)	(82,816)	78,369
NET INCOME (LOSS) FROM DISCONTINUED OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	418,877	(48,110)	28,299
NET INCOME (LOSS) ALLOCATED TO COMMON UNITHOLDERS	$ 247,724	$ (130,926)	$ 106,668
BASIC INCOME (LOSS) PER COMMON UNIT
(Loss) Income From Continuing Operations	$ (1.39)	$ (0.68)	$ 0.73
Income (Loss) From Discontinued Operations, net of Tax	3.41	(0.40)	0.26
Net Income (Loss)	2.01	(1.08)	0.99
DILUTED INCOME (LOSS) PER COMMON UNIT
(Loss) Income From Continuing Operations	(1.39)	(0.68)	0.70
Income (Loss) From Discontinued Operations, net of Tax	3.41	(0.40)	0.25
Net Income (Loss)	$ 2.01	$ (1.08)	$ 0.95
BASIC WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	123,017,064	120,991,340	108,091,486
DILUTED WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	123,017,064	120,991,340	111,850,621

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 43,217	$ 110,528	$ 354,939	$ (169,289)	$ 110,912	$ 56,769	$ (173,579)	$ (63,707)	$ 339,395	$ (69,605)	$ 143,874
Other comprehensive (loss) income									(9)	13	(1,671)
Comprehensive income (loss)									$ 339,386	$ (69,592)	$ 142,203

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Thousands	Total	Accumulated other comprehensive income (loss)	Noncontrolling interests	General Partner	Class B Perpetual Preferred Units	Class B Perpetual Preferred UnitsClass B Perpetual Preferred Units	Limited Partner	Limited PartnerCommon units
Beginning Balance (in units) at Mar. 31, 2016								104,169,573
Beginning Balance at Mar. 31, 2016	$ 1,694,065	$ (157)	$ 37,707	$ (50,811)			$ 1,707,326
Increase (Decrease) in Partnership Capital
Distributions to general and common unit partners and preferred unitholders (Note 10)	(181,581)			(287)			(181,294)
Distributions to noncontrolling interest owners	(3,292)		(3,292)
Contributions	721		1,173	49			(501)
Business combinations (in units)								218,617
Business combinations	3,940						3,940
Purchase of noncontrolling interest	(12,817)		(12,602)				(215)
Repurchase of warrants	0
Equity issued pursuant to incentive compensation plan (in units)								2,350,082
Equity issued pursuant to incentive compensation plan (Note 10)	68,414						68,414
Accretion of beneficial conversion feature of Class A convertible preferred units (Note 10)	(8,999)						(8,999)
Transfer of redeemable noncontrolling interest	(3,072)		(3,072)
Units issued, net of offering costs (in units)								13,441,135
Units issued, net of offering costs (Note 10)	287,136			288			286,848
Allocation of value to beneficial conversion feature of Class A convertible preferred units (Note 10)	131,534						131,534
Issuance of warrants, net of offering costs (Note 10)	48,550						48,550
Net (loss) income	143,874		6,832	232			136,810
Other comprehensive (loss) income	(1,671)	(1,671)
Ending Balance (in units) at Mar. 31, 2017								120,179,407
Ending Balance at Mar. 31, 2017	2,166,802	(1,828)	26,746	(50,529)			2,192,413
Increase (Decrease) in Partnership Capital
Distributions to general and common unit partners and preferred unitholders (Note 10)	(229,792)			(323)			(229,469)
Distributions to noncontrolling interest owners	(3,082)		(3,082)
Contributions	23		23
Sawtooth joint venture (Note 16)	59,233		76,214				(16,981)
Business combinations							0
Purchase of noncontrolling interest	(22,883)		(16,638)				(6,245)
Redeemable noncontrolling interest valuation adjustment	(5,825)						(5,825)
Repurchase of warrants	(10,549)						(10,549)
Equity issued pursuant to incentive compensation plan (in units)								2,260,011
Equity issued pursuant to incentive compensation plan (Note 10)	34,651			28			34,623
Common unit repurchases and cancellations (in units)								(1,574,346)
Common unit repurchases and cancellations (Note 10)	(15,817)						(15,817)
Warrants exercised (in units)								607,653
Warrants exercised (Note 10)	6						6
Accretion of beneficial conversion feature of Class A convertible preferred units (Note 10)	(18,781)						(18,781)
Units issued, net of offering costs (in units)						8,400,000
Units issued, net of offering costs (Note 10)	202,731			100	$ 202,731
Net (loss) income	(70,635)		240	5			(70,880)
Other comprehensive (loss) income	13	13
Ending Balance (in units) at Mar. 31, 2018						8,400,000		121,472,725
Ending Balance at Mar. 31, 2018	2,086,095	(1,815)	83,503	(50,819)	202,731		1,852,495
Increase (Decrease) in Partnership Capital
Distributions to general and common unit partners and preferred unitholders (Note 10)	(236,633)			(330)			(236,303)
Contributions	169		169
Sawtooth joint venture (Note 16)	(854)		(791)				(63)
Business combinations							0
Purchase of noncontrolling interest	(3,960)		(3,927)				(33)
Redeemable noncontrolling interest valuation adjustment	(3,349)						(3,349)
Repurchase of warrants	(14,988)						(14,988)
Equity issued pursuant to incentive compensation plan (in units)								2,833,968
Equity issued pursuant to incentive compensation plan (Note 10)	39,734			22			39,712
Common unit repurchases and cancellations (in units)								(26,993)
Common unit repurchases and cancellations (Note 10)	(297)						(297)
Warrants exercised (in units)								228,797
Warrants exercised (Note 10)	2						2
Accretion of beneficial conversion feature of Class A convertible preferred units (Note 10)	(67,239)						(67,239)
Units issued, net of offering costs (Note 10)				100
Net (loss) income	339,841		(20,206)	387			359,660
Other comprehensive (loss) income	(9)	(9)
Ending Balance (in units) at Mar. 31, 2019						8,400,000		124,508,497
Ending Balance at Mar. 31, 2019	2,277,818	(255)	$ 58,748	(50,603)	$ 202,731		2,067,197
Increase (Decrease) in Partnership Capital
Cumulative effect adjustment for adoption of ASC 606 (Note 15)	139,306
Cumulative effect adjustment for adoption of ASC 606 (Note 15) | General Partner				139
Cumulative effect adjustment for adoption of ASC 606 (Note 15) | Limited Partner							139,167
Cumulative effect adjustment for adoption of ASU 2016-01 (Note 2)	$ 0
Cumulative effect adjustment for adoption of ASU 2016-01 (Note 2) | General Partner				$ (2)
Cumulative effect adjustment for adoption of ASU 2016-01 (Note 2) | Limited Partner		$ 1,569					$ (1,567)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
OPERATING ACTIVITIES:
Net income (loss)	$ 339,395	$ (69,605)	$ 143,874
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
(Income) loss from discontinued operations, net of tax	(418,850)	47,128	(28,327)
Depreciation and amortization, including amortization of debt issuance costs	221,674	219,983	189,369
Loss (gain) on early extinguishment or revaluation of liabilities, net	6,967	43,917	(18,010)
Gain on termination of a storage sublease agreement	0	0	(16,205)
Non-cash equity-based compensation expense	41,367	35,241	53,102
Loss (gain) on disposal or impairment of assets, net	34,296	(17,118)	(208,982)
Provision for doubtful accounts	381	584	(739)
Net adjustments to fair value of commodity derivatives	(10,817)	41,263	15,376
Equity in earnings of unconsolidated entities	(2,533)	(7,539)	(3,830)
Distributions of earnings from unconsolidated entities	2,206	4,632	3,564
Lower of cost or market value adjustment	14,305	410	(648)
Revaluation of investments	0	0	14,365
Other	(485)	(440)	(7,810)
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable-trade and affiliates	(185,717)	(214,750)	(234,750)
Inventories	(10,093)	58,227	(71,430)
Other current and noncurrent assets	43,996	(31,689)	(37,758)
Accounts payable-trade and affiliates	87,739	197,273	221,217
Other current and noncurrent liabilities	(12,308)	(7,169)	5,478
Net cash provided by operating activities-continuing operations	151,523	300,348	17,856
Net cash provided by (used in) operating activities-discontinued operations	185,727	(162,381)	(42,894)
Net cash provided by (used in) operating activities	337,250	137,967	(25,038)
INVESTING ACTIVITIES:
Capital expenditures	(455,586)	(133,761)	(302,762)
Acquisitions, net of cash acquired	(300,614)	(19,897)	(41,928)
Net settlements of commodity derivatives	(10,173)	(39,113)	9,648
Proceeds from sales of assets	16,177	33,844	28,232
Proceeds from divestitures of businesses and investments, net	335,809	329,780	134,370
Transaction with Victory Propane (Note 13)	0	(6,424)	0
Investments in unconsolidated entities	(389)	(21,465)	(2,105)
Distributions of capital from unconsolidated entities	1,440	11,969	9,692
Repayments on loan for natural gas liquids facility	10,336	10,052	8,916
Loan to affiliate	(1,515)	(2,510)	(3,200)
Repayments on loan to affiliate	0	4,160	655
Payment to terminate development agreement	0	0	(16,875)
Net cash (used in) provided by investing activities-continuing operations	(404,515)	166,635	(175,357)
Net cash provided by (used in) investing activities-discontinued operations	857,988	103,947	(187,769)
Net cash (used in) provided by investing activities	453,473	270,582	(363,126)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	4,098,500	2,434,500	1,700,000
Payments on revolving credit facilities	(3,897,000)	(2,279,500)	(2,733,500)
Issuance of senior unsecured notes	0	0	1,200,000
Repayment and repurchase of senior secured and senior unsecured notes	(737,058)	(486,699)	(21,193)
Payments on other long-term debt	(653)	(877)	(46,153)
Debt issuance costs	(1,383)	(2,700)	(33,558)
Contributions from general partner	0	0	49
Contributions from noncontrolling interest owners, net	169	23	672
Distributions to general and common unit partners and preferred unitholders	(236,633)	(225,067)	(181,581)
Distributions to noncontrolling interest owners	0	(3,082)	(3,292)
Proceeds from sale of preferred units, net of offering costs	0	202,731	234,975
Repurchase of warrants	(14,988)	(10,549)	0
Common unit repurchases and cancellations	(297)	(15,817)	0
Proceeds from sale of common units, net of offering costs	0	0	287,136
Payments for settlement and early extinguishment of liabilities	(4,577)	(3,408)	(28,468)
Net cash (used in) provided by financing activities-continuing operations	(793,920)	(390,445)	375,087
Net cash used in financing activities-discontinued operations	(325)	(3,836)	(3,633)
Net cash (used in) provided by financing activities	(794,245)	(394,281)	371,454
Net (decrease) increase in cash and cash equivalents	(3,522)	14,268	(16,710)
Cash and cash equivalents, beginning of period	22,094	7,826	24,536
Cash and cash equivalents, end of period	18,572	22,094	7,826
Supplemental cash flow information:
Cash interest paid	170,632	192,938	117,912
Income taxes paid (net of income tax refunds)	2,423	1,843	2,022
Supplemental non-cash investing and financing activities:
Distributions declared but not paid to Class B preferred unitholders	4,725	4,725	0
Accrued capital expenditures	19,121	12,123	1,758
Value of common units issued in business combinations			3,940
Limited Partner
FINANCING ACTIVITIES:
Repurchase of warrants	(14,988)	(10,549)
Supplemental non-cash investing and financing activities:
Value of common units issued in business combinations	$ 0	$ 0	$ 3,940

Nature of Operations and Organi

Nature of Operations and Organization	12 Months Ended
	Mar. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Organization	Nature of Operations and Organization NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership formed in September 2010. NGL Energy Holdings LLC serves as our general partner. At March 31, 2019 , our operations included: • Our Crude Oil Logistics segment purchases crude oil from producers and marketers and transports it to refineries or for resale at pipeline injection stations, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs, and provides storage, terminaling, trucking, marine and pipeline transportation services through its owned assets. • Our Water Solutions segment provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production and for the disposal of solids such as tank bottoms, drilling fluids and drilling muds and performs truck and frac tank washouts. In addition, our Water Solutions segment sells the recovered hydrocarbons that result from performing these services and sells freshwater to producers for exploration and production activities. • Our Liquids segment supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada using its leased underground storage and fleet of leased railcars, markets regionally through its 27 owned terminals throughout the United States, and provides terminaling and storage services at its salt dome storage facility joint venture in Utah. See Note 16 for a discussion of the joint venture of our Sawtooth Caverns, LLC (“Sawtooth”) business. • Our Refined Products and Renewables segment conducts gasoline, diesel, ethanol, and biodiesel marketing operations , purchase s refined petroleum and renewable products primarily in the Gulf Coast, West Coast and Midwest regions of the United States and schedule s them for delivery at various locations throughout the country. See below for a discussion of the sale of a portion of our Refined Products and Renewables segment. Recent Developments On September 30, 2019, we completed the sale of TransMontaigne Product Services, LLC (“TPSL”) and associated assets to Trajectory Acquisition Company, LLC (“Trajectory”) for total consideration of approximately $233.8 million , including equity consideration, inventory and net working capital (see Note 17 ). TPSL made up a portion of our Refined Products and Renewables segment. The divested assets include (i) TPSL Terminaling Services Agreement with TransMontaigne Partners LP, including the exclusive rights to utilize 19 terminals; (ii) line space along Colonial and Plantation Pipelines; (iii) two wholly-owned refined products terminals in Georgia that we acquired in January 2019 and multiple third-party throughput agreements; and (iv) all associated customer contracts, inventory and other working capital associated with the assets. In December 2019, the Partnership formalized a plan and received approval to divest of its gas blending business in the southeastern and eastern regions of the United States (“Gas Blending”) and its refined products marketing business in the mid-continent region of the United States (“Mid-Con”). The Partnership had determined that these businesses were no longer core to the Partnership’s strategy. These transactions represent a strategic shift in our operations and will have a significant effect on our operations and financial results going forward. Accordingly, the results of operations and cash flows related to TPSL, Mid-Con and Gas Blending have been classified as discontinued operations for all periods presented, and prior periods have been retrospectively adjusted in the consolidated statements of operations and consolidated statements of cash flows. In addition, the assets and liabilities related to TPSL and certain assets and liabilities, particularly inventory, derivatives and leases, related to Mid-Con and Gas Blending have been classified as held for sale in our March 31, 2019 and 2018 consolidated balance sheets. On January 3, 2020, we completed the sale of Mid-Con to a third-party. See Note 17 for a further discussion of these transactions. On March 30, 2018, we sold a portion of our Retail Propane segment to DCC LPG (“DCC”) for net proceeds of $212.4 million in cash. The Retail Propane businesses subject to this transaction consisted of our operations across the Mid-Continent and Western portions of the United States. On July 10, 2018, we completed the sale of virtually all of our remaining Retail Propane segment to Superior Plus Corp. (“Superior”) for total consideration of $889.8 million in cash. We retained our 50% ownership interest in Victory Propane, LLC (“Victory Propane”), which we subsequently sold on August 14, 2018 (see Note 2 ). These transactions represent a strategic shift in our operations and will have a significant effect on our operations and financial results going forward. Accordingly, the results of operations and cash flows related to our former Retail Propane segment (including equity in earnings of Victory Propane) have been classified as discontinued operations for all periods presented and prior periods have been retrospectively adjusted in the consolidated statements of operations and consolidated statements of cash flows. In addition, the assets and liabilities related to our former Retail Propane segment have been classified as held for sale within our March 31, 2018 consolidated balance sheet. See Note 17 for a further discussion of the transaction.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies Basis of Presentation Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). The accompanying consolidated financial statements include our accounts and those of our controlled subsidiaries. Intercompany transactions and account balances have been eliminated in consolidation. Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. We also own an undivided interest in a crude oil pipeline, and include our proportionate share of assets, liabilities, and expenses related to this pipeline in our consolidated financial statements. Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amount of assets and liabilities reported at the date of the consolidated financial statements and the amount of revenues and expenses reported during the periods presented. Critical estimates we make in the preparation of our consolidated financial statements include, among others, determining the fair value of assets and liabilities acquired in acquisitions, the fair value of derivative instruments, the collectibility of accounts receivable, the recoverability of inventories, useful lives and recoverability of property, plant and equipment and amortizable intangible assets, the impairment of long-lived assets and goodwill, the fair value of asset retirement obligations, the value of equity-based compensation, accruals for environmental matters and estimating certain revenues. Although we believe these estimates are reasonable, actual results could differ from those estimates. Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value is based upon assumptions that market participants would use when pricing an asset or liability. We use the following fair value hierarchy, which prioritizes valuation technique inputs used to measure fair value into three broad levels: • Level 1: Quoted prices in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2: Inputs (other than quoted prices included within Level 1) that are either directly or indirectly observable for the asset or liability, including (i) quoted prices for similar assets or liabilities in active markets, (ii) quoted prices for identical or similar assets or liabilities in inactive markets, (iii) inputs other than quoted prices that are observable for the asset or liability, and (iv) inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and forward commodity contracts. We determine the fair value of all of our derivative financial instruments utilizing pricing models for similar instruments. Inputs to the pricing models include publicly available prices and forward curves generated from a compilation of data gathered from third parties. • Level 3: Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall into different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to a fair value measurement requires judgment, considering factors specific to the asset or liability. Derivative Financial Instruments We record all derivative financial instrument contracts at fair value in our consolidated balance sheets except for certain physical contracts that qualify for the normal purchase and normal sale election . Under this accounting policy election, we do not record the physical contracts at fair value at each balance sheet date; instead, we record the purchase or sale at the contracted value once the delivery occurs. We have not designated any financial instruments as hedges for accounting purposes. All changes in the fair value of our physical contracts that do not qualify as normal purchases and normal sales and settlements (whether cash transactions or non-cash mark-to-market adjustments) are reported either within revenue (for sales contracts) or cost of sales (for purchase contracts) in our consolidated statements of operations, regardless of whether the contract is physically or financially settled. We utilize various commodity derivative financial instrument contracts to attempt to reduce our exposure to price fluctuations. We do not enter into such contracts for trading purposes. Changes in assets and liabilities from commodity derivative financial instruments result primarily from changes in market prices, newly originated transactions, and the timing of settlements and are reported within cost of sales on the consolidated statements of operations, along with related settlements. We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. However, net unbalanced positions can exist or are established based on our assessment of anticipated market movements. Inherent in the resulting contractual portfolio are certain business risks, including commodity price risk and credit risk. Commodity price risk is the risk that the market value of crude oil, natural gas liquids, or refined and renewables products will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. Procedures and limits for managing commodity price risks and credit risks are specified in our market risk policy and credit policy, respectively. Open commodity positions and market price changes are monitored daily and are reported to senior management and to marketing operations personnel. Credit risk is monitored daily and exposure is minimized through customer deposits, restrictions on product liftings, letters of credit, and entering into master netting agreements that allow for offsetting counterparty receivable and payable balances for certain transactions. Cost of Sales We include all costs we incur to acquire products, including the costs of purchasing, terminaling, and transporting inventory, prior to delivery to our customers, in cost of sales. Cost of sales excludes depreciation of our property, plant and equipment. Depreciation and Amortization Depreciation and amortization in our consolidated statements of operations includes all depreciation of our property, plant and equipment and amortization of intangible assets other than debt issuance costs, for which the amortization is recorded to interest expense, and certain contract-based intangible assets, for which the amortization is recorded to cost of sales. Income Taxes We qualify as a partnership for income tax purposes. As such, we generally do not pay United States federal income tax. Rather, each owner reports his or her share of our income or loss on his or her individual tax return. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined, as we do not have access to information regarding each partner’s basis in the Partnership. We have certain taxable corporate subsidiaries in the United States and Canada, and our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales. Our fiscal years 2015 to 2018 generally remain subject to examination by federal, state, and Canadian tax authorities. We utilize the asset and liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply in the years in which these temporary differences are expected to be recovered or settled. Changes in tax rates are recognized in income in the period that includes the enactment date. A publicly traded partnership is required to generate at least 90% of its gross income (as defined for federal income tax purposes) from certain qualifying sources. Income generated by our taxable corporate subsidiaries is excluded from this qualifying income calculation. Although we routinely generate income outside of our corporate subsidiaries that is non-qualifying, we believe that at least 90% of our gross income has been qualifying income for each of the calendar years since our IPO. During the year ended March 31, 2019 , we recognized a deferred tax liability of $16.3 million as a result of acquiring a corporation in connection with one of our acquisitions (see Note 4 ). The deferred tax liability is the tax effected cumulative temporary difference between the GAAP basis and tax basis of the acquired assets within the corporation. For GAAP purposes, certain of the acquired assets will be depreciated and amortized over time which will lower the GAAP basis. The deferred tax benefit recorded for the year ended March 31, 2019 is $1.5 million with an effective tax rate of 31% . The deferred tax liability is $14.8 million at March 31, 2019 and is included within other noncurrent liabilities in our consolidated balance sheet. We evaluate uncertain tax positions for recognition and measurement in the consolidated financial statements. To recognize a tax position, we determine whether it is more likely than not that the tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position. A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the consolidated financial statements. We had no material uncertain tax positions that required recognition in our consolidated financial statements at March 31, 2019 or 2018 . Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand and time deposits, and funds invested in highly liquid instruments with maturities of three months or less at the date of purchase. At times, certain account balances may exceed federally insured limits. Accounts Receivable and Concentration of Credit Risk We operate in the United States and Canada. We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions. The allowance for doubtful accounts is based on our assessment of the collectibility of customer accounts, which assessment considers the overall creditworthiness of customers and any specific disputes. Accounts receivable are considered past due or delinquent based on contractual terms. We write off accounts receivable against the allowance for doubtful accounts when collection efforts have been exhausted. We execute netting agreements with certain customers to mitigate our credit risk. Receivables and payables are reflected at a net balance to the extent a netting agreement is in place and we intend to settle on a net basis. Our accounts receivable consist of the following at the dates indicated: March 31, 2019 March 31, 2018 Segment Gross Allowance for Net Gross Allowance for Net (in thousands) Crude Oil Logistics $ 514,243 $ (15 ) $ 514,228 $ 404,865 $ — $ 404,865 Water Solutions 57,526 (3,157 ) 54,369 59,958 (2,952 ) 57,006 Liquids 134,050 (177 ) 133,873 131,006 (20 ) 130,986 Refined Products and Renewables 295,984 (667 ) 295,317 228,574 (879 ) 227,695 Corporate and Other 416 — 416 — — — Total $ 1,002,219 $ (4,016 ) $ 998,203 $ 824,403 $ (3,851 ) $ 820,552 Changes in the allowance for doubtful accounts are as follows for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Allowance for doubtful accounts, beginning of period $ (3,851 ) $ (3,604 ) $ (5,340 ) Provision for doubtful accounts (381 ) (584 ) 739 Write off of uncollectible accounts 216 337 997 Allowance for doubtful accounts, end of period $ (4,016 ) $ (3,851 ) $ (3,604 ) Amounts in the tables above do not include accounts receivable or allowance for doubtful accounts related to TPSL, as these amounts have been classified as current assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the tables above do not include accounts receivable or allowance for doubtful accounts related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). We did not have any customers that represented over 10% of consolidated revenues for fiscal years 2019 , 2018 and 2017 . Inventories Our inventories are valued at the lower of cost or net realizable value, with cost determined using either the weighted-average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage, and with net realizable value defined as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. In performing this analysis, we consider fixed-price forward commitments. Inventories consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Crude oil $ 51,359 $ 77,351 Natural gas liquids: Propane 33,478 38,910 Butane 15,294 12,613 Other 7,482 6,515 Refined products and renewables: Diesel 9,186 12,752 Ethanol 14,650 5,542 Biodiesel 4,679 7,966 Total $ 136,128 $ 161,649 Amounts in the table above do not include inventory related to Mid-Con, Gas Blending and TPSL, as these amounts have been classified as current assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include inventory related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). Investments in Unconsolidated Entities Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. Investments in partnerships and limited liability companies, unless our investment is considered to be minor, and investments in unincorporated joint ventures are also accounted for using the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheets; instead, our ownership interests are reported within investments in unconsolidated entities on our consolidated balance sheets. Under the equity method, the investment is recorded at acquisition cost, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses, distributions paid, and amortization of any excess investment. Excess investment is the amount by which our total investment exceeds our proportionate share of the net assets of the investee. We consider distributions received from unconsolidated entities which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and are classified as operating activities in our consolidated statements of cash flows. We consider distributions received from unconsolidated entities in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in our consolidated statements of cash flows. Our investments in unconsolidated entities consist of the following at the dates indicated: Ownership Date Acquired March 31, Entity Segment Interest (1) or Formed 2019 2018 (in thousands) Water services company (2) Water Solutions 50% August 2018 $ 920 $ — Natural gas liquids terminal company (3) Liquids 50% March 2019 207 — Water treatment and disposal facility (4) Water Solutions —% August 2015 — 2,094 E Energy Adams, LLC (5) Refined Products and Renewables —% December 2013 — 15,142 Victory Propane (6) Corporate and Other —% April 2015 — — Total $ 1,127 $ 17,236 (1) Ownership interest percentages are at March 31, 2019 . (2) This is an investment in an unincorporated joint venture that we acquired as part of an acquisition in August 2018. See Note 4 for a further discussion. (3) This is an investment in an unincorporated joint venture that we acquired as part of an acquisition in March 2019. See Note 4 for a further discussion. (4) This is an investment in an unincorporated joint venture. On February 28, 2019, we sold this investment as part of the sale of our South Pecos water disposal business. See Note 16 for a further discussion. (5) On May 3, 2018, we sold our previously held 20% interest in E Energy Adams, LLC for net proceeds of $18.6 million and recorded a gain on disposal of $3.0 million during the year ended March 31, 2019 within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. (6) On August 14, 2018, we sold our previously held 50% interest in Victory Propane. See Note 13 for a further discussion. Combined summarized financial information for all of our unconsolidated entities is as follows for the dates and periods indicated: Balance sheets: March 31, 2019 2018 (in thousands) Current assets $ 1,328 $ 24,431 Noncurrent assets $ 519 $ 99,164 Current liabilities $ 178 $ 16,787 Noncurrent liabilities $ — $ 10,620 Statements of operations: March 31, 2019 2018 2017 (in thousands) Revenues $ 21,036 $ 182,820 $ 180,632 Cost of sales $ 9,919 $ 114,890 $ 114,316 Net income $ 5,506 $ 26,438 $ 19,462 At March 31, 2019 , cumulative equity earnings and cumulative distributions of our unconsolidated entities since they were acquired were $1.9 million and $3.0 million , respectively. Variable Interest Entity Victory Propane was formed as a joint venture in April 2015 by us and an unrelated third party. The business purpose of Victory Propane is to acquire and/or develop retail propane operations in a defined geographic area. In conjunction with the formation of Victory Propane, we agreed to provide Victory Propane a revolving line of credit of $5.0 million and have concluded that Victory Propane is a variable interest entity because the equity of Victory Propane is not sufficient to fund its activities without additional subordinated financial support. On August 14, 2018, we sold our interest in Victory Propane. Our equity in earnings in Victory Propane has been classified as discontinued operations for all periods presented, as discussed further in Note 1 and Note 17 . Other Noncurrent Assets Other noncurrent assets consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Loan receivable (1) $ 19,474 $ 29,463 Line fill (2) 33,437 34,897 Minimum shipping fees - pipeline commitments (3) 23,494 88,757 Other 37,452 49,837 Total $ 113,857 $ 202,954 (1) Represents the noncurrent portion of a loan receivable associated with our financing of the construction of a natural gas liquids facility that is utilized by a third party and the noncurrent portion of a loan receivable with Victory Propane (see Note 13). (2) Represents minimum volumes of product we are required to leave on certain third-party owned pipelines under long-term shipment commitments. At March 31, 2019 , line fill consisted of 335,069 barrels of crude oil and 262,000 barrels of propane. At March 31, 2018 , line fill consisted of 360,425 barrels of crude oil and 262,000 barrels of propane. Line fill held in pipelines we own is included within property, plant and equipment (see Note 5). (3) Represents the minimum shipping fees paid in excess of volumes shipped, or deficiency credits, for two contracts with crude oil pipeline operators. This amount can be recovered when volumes shipped exceed the minimum monthly volume commitment (see Note 9). During the three months ended June 30, 2018, we entered into a definitive agreement, as described further in Note 13, in which we agreed to provide the benefit of our deficiency credit under one of these contracts. As a result of providing this benefit to the third party, we wrote off $67.7 million of these deficiency credits and recorded a loss within loss (gain) on disposal or impairment of assets, net . Under the remaining other contract for which we have the future benefit, we currently have 13 months in which to ship the excess volumes. Amounts in the table above do not include other noncurrent assets related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include other noncurrent assets related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). Accrued Expenses and Other Payables Accrued expenses and other payables consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Accrued compensation and benefits $ 19,312 $ 17,778 Excise and other tax liabilities 10,481 8,279 Derivative liabilities 4,960 8,321 Accrued interest 24,882 39,947 Product exchange liabilities 5,945 1,116 Gavilon legal matter settlement (Note 9) 12,500 — Deferred gain on sale of general partner interest in TLP (1) — 30,113 Other 29,679 31,688 Total $ 107,759 $ 137,242 (1) See Note 15 for a discussion of the accounting for the deferred gain upon adoption of ASC 606. Amounts in the table above do not include accrued expenses and other payables related to TPSL and Mid-Con and Gas Blending derivative liabilities, as these amounts have been classified as current liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include accrued expenses and other payables related to our former Retail Propane segment, as these amounts have been classified as current liabilities held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). Property, Plant and Equipment We record property, plant and equipment at cost, less accumulated depreciation. Acquisitions and improvements are capitalized, and maintenance and repairs are expensed as incurred. As we dispose of assets, we remove the cost and related accumulated depreciation from the accounts, and any resulting gain or loss is included within loss (gain) on disposal or impairment of assets, net . We compute depreciation expense of our property, plant and equipment using the straight-line method over the estimated useful lives of the assets (see Note 5 ). Intangible Assets Our intangible assets include contracts and arrangements acquired in business combinations, including customer relationships, customer commitments, pipeline capacity rights, rights-of-way and easements, water rights, executory contracts and other agreements, covenants not to compete, and trade names. In addition, we capitalize certain debt issuance costs associated with the revolving credit facilities. We amortize the majority of our intangible assets on a straight-line basis over the estimated useful lives of the assets (see Note 7 ). We amortize debt issuance costs over the terms of the related debt using a method that approximates the effective interest method. Impairment of Long-Lived Assets We evaluate the carrying value of our long-lived assets (property, plant and equipment and amortizable intangible assets) for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is less than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group. When we cease to use an acquired trade name, we test the trade name for impairment using the relief from royalty method and we begin amortizing the trade name over its estimated useful life as a defensive asset. See Note 5 and Note 7 for a further discussion of long-lived asset impairments recognized in the consolidated statements of operations. We evaluate our equity method investments for impairment when we believe the current fair value may be less than the carrying amount and record an impairment if we believe the decline in value is other than temporary. Goodwill Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Business combinations are accounted for using the “acquisition method” (see Note 4 ). We expect that all of our goodwill at March 31, 2019 is deductible for federal income tax purposes. Goodwill and indefinite-lived intangible assets are not amortized, but instead are evaluated for impairment at least annually. We perform our annual assessment of impairment during the fourth quarter of our fiscal year, and more frequently if circumstances warrant. To perform this assessment, we first consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. If we conclude that it is more likely than not that the fair value of a reporting unit does not exceed its carrying amount, we calculate the fair value for the reporting unit and compare the amount to its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its fair value, goodwill is considered to be impaired and the goodwill balance is reduced by the difference between the fair value and carrying amount of the reporting unit. Estimates and assumptions used to perform the impairment evaluation are inherently uncertain and can significantly affect the outcome of the analysis. The estimates and assumptions we used in the annual goodwill impairment assessment included market participant considerations and future forecasted operating results. Changes in operating results and other assumptions could materially affect these estimates. See Note 6 for a further discussion and analysis of our goodwill impairment assessment. Product Exchanges Quantities of products receivable or returnable under exchange agreements are reported within prepaid expenses and other current assets and within accrued expenses and other payables in our consolidated balance sheets. We estimate the value of product exchange assets and liabilities based on the weighted-average cost basis of the inventory we have delivered or will deliver on the exchange, plus or minus location differentials. Product exchanges related to TPSL have been classified as current assets and current liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, product exchanges related to our former Retail Propane segment have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). Noncontrolling Interests Noncontrolling interests represent the portion of certain consolidated subsidiaries that are owned by third parties. Amounts are adjusted by the noncontrolling interest holder’s proportionate share of the subsidiaries’ earnings or losses each period and any distributions that are paid. Noncontrolling interests are reported as a component of equity, unless the noncontrolling interest is considered redeemable, in which case the noncontrolling interest is recorded between liabilities and equity (mezzanine or temporary equity) in our consolidated balance sheet. The redeemable noncontrolling interest is adjusted at each balance sheet date to its maximum redemption value if the amount is greater than the carrying value. The redeemable noncontrolling interest is classified as held for sale in our March 31, 2018 consolidated balance sheet (see Note 17 ). The following table summarizes changes in our redeemable noncontrolling interest in our consolidated balance sheets (in thousands): Balance at March 31, 2017 $ 3,072 Net income attributable to redeemable noncontrolling interest 1,030 Redeemable noncontrolling interest valuation adjustment 5,825 Balance at March 31, 2018 9,927 Net loss attributable to redeemable noncontrolling interest (446 ) Redeemable noncontrolling interest valuation adjustment 3,349 Disposal of redeemable noncontrolling interest (12,830 ) Balance at March 31, 2019 $ — Acquisitions To determine if a transaction should be accounted for as a business combination or an acquisition of assets, we first calculate the relative fair values of the assets acquired. If substantially all of the relative fair value is concentrated in a single asset or group of similar assets, or if not but the transaction does not include a significant process (does not meet the definition of a business), we record the transaction as an acquisition of assets. For acquisitions of assets, the purchase price is allocated based on the relative fair values. For an acquisition of assets, goodwill is not recorded. All other transactions are recorded as business combinations. We record the assets acquired and liabilities assumed in a business combination at their acquisition date fair values. For a business combination, the excess of the purchase price over the net fair value of acquired assets and assumed liabilities is recorded as goodwill, which is not amortized but instead is evaluated for impairment at least annually (as described above). Pursuant to GAAP, an entity is allowed a reasonable period of time (not to exceed one year) to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. As discussed in Note 4 , certain of our acquisitions are still within this measurement period, and as a result, the acquisition date fair values we have recorded for the assets acquired and liabilities assumed are subject to change. Recent Accounting Pronouncements In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-13, “Financial Instruments-Credit Losses.” The ASU requires a financial asset (or a group of financial assets) measured at amortized cost to be presented at the net amount expected to be collected, which would include accounts receivable. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectibility of the reported amount. The ASU is effective for the Partnership beginning April 1, 2020, and requires a modified retrospective method of adoption, although early adoption is permitted. We are currently in the process of assessing the impact of this ASU on our consolidated financial statements. In February 2016, the FASB issued ASC 842, “Leases.” This will replace previous lease accounting guidance in GAAP. The new guidance requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. It also retains a distinction between finance leases and operating leases. This guidance is effective for the Partnership beginning April 1, 2019. We evaluated our current leases and other contracts that may be considered leases under the new standard and the impact on our internal controls, accounting poli

Income (Loss) Per Common Unit

Income (Loss) Per Common Unit	12 Months Ended
	Mar. 31, 2019
Earnings Per Unit [Abstract]
Income (Loss) Per Common Unit	Income (Loss) Per Common Unit The following table presents our calculation of basic and diluted weighted average common units outstanding for the periods indicated: Year Ended March 31, 2019 2018 2017 Weighted average common units outstanding during the period: Common units - Basic 123,017,064 120,991,340 108,091,486 Effect of Dilutive Securities: Performance awards — — 173,087 Warrants — — 3,586,048 Common units - Diluted 123,017,064 120,991,340 111,850,621 For the year ended March 31, 2019 , the Service Awards (as defined herein), warrants and the Class A Preferred Units (as defined herein) were considered antidilutive. Due to the termination of the Performance Award plan (see Note 10), there were no outstanding Performance Awards (as defined herein) as of March 31, 2019. For the year ended March 31, 2018, the Service Awards, Performance Awards, warrants and Class A Preferred Units were considered antidilutive. For the year ended March 31, 2017, the Service Awards and Class A Preferred Units were considered antidilutive. Our income (loss) per common unit is as follows for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands, except unit and per unit amounts) (Loss) income from continuing operations $ (79,455 ) $ (22,477 ) $ 115,547 Less: Continuing operations loss (income) attributable to noncontrolling interests 20,206 (240 ) (6,832 ) Net (loss) income from continuing operations attributable to NGL Energy Partners LP (59,249 ) (22,717 ) 108,715 Less: Distributions to preferred unitholders (1) (111,936 ) (59,697 ) (30,142 ) Less: Continuing operations net loss (income) allocated to general partner (2) 32 (53 ) (204 ) Less: Repurchase of warrants (3) — (349 ) — Net (loss) income from continuing operations allocated to common unitholders $ (171,153 ) $ (82,816 ) $ 78,369 Income (loss) from discontinued operations, net of tax $ 418,850 $ (47,128 ) $ 28,327 Less: Discontinued operations loss (income) attributable to redeemable noncontrolling interests 446 (1,030 ) — Less: Discontinued operations (income) loss allocated to general partner (2) (419 ) 48 (28 ) Net income (loss) from discontinued operations allocated to common unitholders $ 418,877 $ (48,110 ) $ 28,299 Net income (loss) allocated to common unitholders $ 247,724 $ (130,926 ) $ 106,668 Basic income (loss) per common unit (Loss) income from continuing operations $ (1.39 ) $ (0.68 ) $ 0.73 Income (loss) from discontinued operations, net of tax $ 3.41 $ (0.40 ) $ 0.26 Net income (loss) $ 2.01 $ (1.08 ) $ 0.99 Diluted income (loss) per common unit (Loss) income from continuing operations $ (1.39 ) $ (0.68 ) $ 0.70 Income (loss) from discontinued operations, net of tax $ 3.41 $ (0.40 ) $ 0.25 Net income (loss) $ 2.01 $ (1.08 ) $ 0.95 Basic weighted average common units outstanding 123,017,064 120,991,340 108,091,486 Diluted weighted average common units outstanding 123,017,064 120,991,340 111,850,621 (1) This amount includes the distribution to preferred unitholders as well as the accretion for the beneficial conversion, as discussed further in Note 10. (2) Net (income) loss allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights. (3) This amount represents the excess of the repurchase price over the fair value of the warrants, as discussed further in Note 10.

Acquisitions

Acquisitions	12 Months Ended
	Mar. 31, 2019
Business Combinations [Abstract]
Acquisitions	Acquisitions The following summarizes our acquisitions during the year ended March 31, 2019 : Water Pipeline Company On April 24, 2018, we acquired the remaining 18.375% interest in NGL Water Pipelines, LLC operating in the Delaware Basin portion of the Permian Basin in West Texas for total consideration of approximately $4.0 million . The acquisition of the remaining interest was accounted for as an equity transaction, no gain or loss was recorded, and the carrying value of the noncontrolling interest was adjusted to reflect the change in ownership interest of the subsidiary. As of the date of the transaction, the 18.375% interest had a carrying value of $3.9 million . Saltwater Water Solutions Facilities During the year ended March 31, 2019 , we acquired six saltwater disposal facilities (including 15 saltwater disposal wells) for total consideration of approximately $116.1 million . As part of these acquisitions, we recorded customer relationship, favorable contract and non-compete agreement intangible assets whereby we estimated the value of these intangible assets using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. The agreements for these acquisitions contemplate post-closing payments for certain working capital items. We are accounting for these transactions as business combinations. The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Property, plant and equipment $ 36,590 Goodwill 50,619 Intangible assets 29,287 Current liabilities (10 ) Other noncurrent liabilities (410 ) Fair value of net assets acquired $ 116,076 As of March 31, 2019 , the allocation of the purchase price is considered preliminary as we are continuing to gather additional information to finalize the fair values of the property, plant and equipment and intangible assets. Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents a premium paid to expand the number of our disposal sites in an oilfield production basin currently serviced by us, thereby enhancing our competitive position as a provider of disposal services in this oilfield production basin. We expect that all of the goodwill will be deductible for federal income tax purposes. The operations of these water solutions facilities have been included in our consolidated statement of operations since their acquisition date. Our consolidated statement of operations for the year ended March 31, 2019 includes revenues of $12.6 million and operating income of $4.9 million that were generated by the operations of these water solutions facilities. We incurred $0.2 million of transaction costs related to these acquisitions during the year ended March 31, 2019 . These amounts are recorded within general and administrative expenses in our consolidated statement of operations. During the year ended March 31, 2019 , we also acquired seven saltwater disposal wells for total consideration of $35.2 million , which we are accounting for as acquisitions of assets. The consideration paid for this transaction was allocated primarily to property, plant and equipment. Freshwater Water Solutions Facilities During the year ended March 31, 2019 , we acquired a ranch and four freshwater facilities (including 27 freshwater wells) and a right-of-way that can be used for pipelines for total consideration of approximately $77.2 million . As part of these acquisitions, we recorded water rights, customer relationship, favorable contract and non-compete agreement intangible assets, whereby we estimated the value of these intangible assets using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. A book/tax difference was created as part of one of these acquisitions and as a result, we have recorded a preliminary noncurrent deferred tax liability of $16.3 million (see Note 2 for a further discussion). We recorded contingent consideration liabilities within accrued expenses and other payables and other noncurrent liabilities in our consolidated balance sheet related to future royalty payments due to the seller. We estimated the contingent consideration for one liability based on the contracted royalty rate, which is a flat rate per barrel, multiplied by the expected volumes of freshwater sold. We estimated the contingent consideration for the other liability based on the contracted royalty rate, which is a flat rate per barrel, multiplied by the expected third party volumes to be transported on the pipeline for the expected useful life of the rights-of-way. These amounts were then discounted to present value using our weighted average cost of capital plus a premium representative of the uncertainty associated with the expected volumes. As of the acquisition date, we recorded a contingent liability of $2.7 million . We assumed land leases with a royalty component as part of the acquisition of certain of these facilities. The acquisition method of accounting requires that executory contracts with unfavorable terms relative to market conditions at the acquisition date be recorded as liabilities in the acquisition accounting. We recorded a liability within other noncurrent liabilities of $0.5 million related to these leases due to the royalty terms being deemed unfavorable. We will amortize this liability based on the volumes processed by the facilities. The agreements for these acquisitions contemplate post-closing payments for certain working capital items. We are accounting for these transactions as business combinations. The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Property, plant and equipment $ 7,123 Goodwill 23,570 Intangible assets 64,015 Investments in unconsolidated entities 2,060 Current liabilities (276 ) Other noncurrent liabilities (19,288 ) Fair value of net assets acquired $ 77,204 As of March 31, 2019 , the allocation of the purchase price is considered preliminary as we are continuing to gather additional information to finalize the fair values of land, other property, plant and equipment, intangible assets, including customer relationships, and the investment in the unconsolidated entity. We are also engaging a third party valuation firm to assist us in this effort. The noncurrent deferred tax liability is also considered preliminary and will be finalized once the fair value of the assets acquired has been finalized. Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents a premium paid to expand our service offerings in an oilfield production basin currently serviced by us, thereby enhancing our competitive position as a provider of disposal and other services in this oilfield production basin. We expect that all of the goodwill will be deductible for federal income tax purposes. The operations of these water solutions facilities have been included in our consolidated statement of operations since their acquisition date. Our consolidated statement of operations for the year ended March 31, 2019 includes revenues of $2.0 million and an operating loss of $1.1 million that were generated by the operations of these water solutions facilities. We incurred $3.7 million of transaction costs related to these acquisitions during the year ended March 31, 2019 . These amounts are recorded within general and administrative expenses in our consolidated statement of operations. During the year ended March 31, 2019 , we also acquired an additional ranch (including 18 freshwater wells) for total consideration of $28.4 million , which we are accounting for as an acquisition of assets. The consideration paid for this transaction was allocated to land and intangible assets. Natural Gas Liquids Terminal Business In March 2019, we completed the acquisition of the natural gas liquids terminal business of DCP Midstream, LP . The acquisition consisted of five propane rail terminals, located in the Eastern United States, a 50% ownership interest in an additional rail terminal, located in the state of Maine, and an import/export terminal located in Chesapeake, Virginia for total consideration of approximately $103.4 million . The import/export terminal has the capability to load and unload ships ranging in size from handy-sized vessels up to very large gas carriers. These terminals complement our existing natural gas liquids portfolio and also create additional opportunities for new and existing customers to supply their business. As part of this acquisition, we recorded a customer relationship intangible asset whereby we estimated the value of this intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. The agreement for this acquisition contemplates post-closing payments for certain working capital items. We are accounting for this transaction as a business combination. The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Inventories $ 15,370 Other current assets 667 Property, plant and equipment 42,413 Goodwill 20,472 Intangible assets 26,900 Investments in unconsolidated entities 204 Current liabilities (2,128 ) Other noncurrent liabilities (524 ) Fair value of net assets acquired $ 103,374 As of March 31, 2019 , the allocation of the purchase price is considered preliminary as we are continuing to gather additional information to finalize the fair values of the property, plant and equipment, intangible assets and the investment in the unconsolidated entity. Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents a premium paid to expand the number of our natural gas liquids terminals in an area currently serviced by us, thereby enhancing our competitive position as a provider of terminaling services in this area. We expect that all of the goodwill will be deductible for federal income tax purposes. The operations of these natural gas liquids terminals have been included in our consolidated statement of operations since their acquisition date. Our consolidated statement of operations for the year ended March 31, 2019 includes revenues of $22.7 million and operating income of $2.4 million that were generated by the operations of these natural gas liquids terminals. We incurred $0.5 million of transaction costs related to this acquisition during the year ended March 31, 2019 . These amounts are recorded within general and administrative expenses in our consolidated statement of operations. Refined Products Terminals In January 2019, we completed the acquisition of two refined products terminals located in Georgia for total consideration of approximately $16.3 million . As part of this acquisition, we recorded a customer relationship intangible asset whereby we estimated the value of this intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. The agreement for this acquisition contemplates post-closing payments for certain working capital items. We are accounting for this transaction as a business combination. The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Inventories $ 327 Other current assets 85 Property, plant and equipment 9,986 Goodwill 1,328 Intangible assets 4,600 Current liabilities (4 ) Fair value of net assets acquired $ 16,322 As of March 31, 2019 , the allocation of the purchase price is considered preliminary as we are continuing to gather additional information to finalize the fair values of the property, plant and equipment and intangible assets. Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents a premium paid to expand the number of our refined products terminals in an area currently serviced by us, thereby enhancing our competitive position as a provider of terminaling services in this area. We expect that all of the goodwill will be deductible for federal income tax purposes. The operations of these refined products terminals have been included in our consolidated statement of operations since their acquisition date. Our consolidated statement of operations for the year ended March 31, 2019 includes revenues of $0.3 million and an operating loss of $0.1 million that were generated by the operations of these refined products terminals. We incurred $0.1 million of transaction costs related to this acquisition during the year ended March 31, 2019 . These amounts are recorded within general and administrative expenses in our consolidated statement of operations. The assets and liabilities of this acquisition and the operations have been classified as discontinued (see Note 1 and Note 17). Retail Propane Businesses During the three months ended June 30, 2018, we acquired three retail propane businesses for total consideration of approximately $19.1 million . We accounted for these transactions as business combinations. On July 9, 2018, and in conjunction with the sale of the Retail Propane segment (see Note 1 ), we acquired the remaining 40% interest in Atlantic Propane, LLC , which was part of our Retail Propane segment, for total consideration of approximately $12.8 million . The acquisition of the remaining interest was accounted for as an equity transaction, no gain or loss was recorded, and the carrying value of the noncontrolling interest was adjusted to reflect the change in ownership interest of the subsidiary. Atlantic Propane, LLC was included in the sale to Superior (see Note 1 ). The assets and liabilities of these retail propane transactions were included in the sale of virtually all of our remaining Retail Propane segment on July 10, 2018 and the operations have been classified as discontinued (see Note 17 ). The following summarizes the status of the preliminary purchase price allocation of acquisitions prior to April 1, 2018: Retail Propane Businesses During the three months ended June 30, 2018, we completed the acquisition accounting for the remaining four retail propane businesses, which were part of the sale of virtually all of our Retail Propane segment (see Note 17 ). The assets and liabilities are included in current assets and current liabilities held for sale in our March 31, 2018 consolidated balance sheet (see Note 17 ). There were no material adjustments to the fair value of assets acquired and liabilities assumed during the three months ended June 30, 2018.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Mar. 31, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Our property, plant and equipment consists of the following at the dates indicated: Estimated March 31, Description Useful Lives 2019 2018 (in years) (in thousands) Natural gas liquids terminal and storage assets 2 - 30 $ 280,106 $ 238,487 Pipeline and related facilities 30 - 40 243,799 243,616 Vehicles and railcars 3 - 25 124,948 121,159 Water treatment facilities and equipment 3 - 30 704,666 601,139 Crude oil tanks and related equipment 2 - 30 225,476 218,588 Barges and towboats 5 - 30 103,735 92,712 Information technology equipment 3 - 7 31,831 29,521 Buildings and leasehold improvements 3 - 40 143,711 147,110 Land 62,379 51,816 Tank bottoms and line fill (1) 20,071 20,118 Other 3 - 20 14,870 11,646 Construction in progress 290,805 77,596 2,246,397 1,853,508 Accumulated depreciation (417,457 ) (341,222 ) Net property, plant and equipment $ 1,828,940 $ 1,512,286 (1) Tank bottoms, which are product volumes required for the operation of storage tanks, are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. Line fill, which represents our portion of the product volume required for the operation of the proportionate share of a pipeline we own, is recorded at historical cost. Amounts in the table above do not include property, plant and equipment and accumulated depreciation related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include property, plant and equipment and accumulated depreciation related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). The following table summarizes depreciation expense and capitalized interest expense for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Depreciation expense $ 101,515 $ 99,954 $ 89,848 Capitalized interest expense $ 482 $ 182 $ 6,887 Amounts in the table above do not include depreciation expense and capitalized interest related to TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ). We record (gains) losses from the sales of property, plant and equipment and any write-downs in value due to impairment within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. The following table summarizes (gains) losses on the disposal or impairment of property, plant and equipment by segment for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Crude Oil Logistics (1) $ 3,489 $ (3,144 ) $ 8,124 Water Solutions 3,067 8,117 7,169 Liquids 993 639 92 Corporate — 8 (1 ) Total $ 7,549 $ 5,620 $ 15,384 (1) Amount for the year ended March 31, 2018 primarily relates to a gain related to the sale of excess pipe, partially offset by losses from the disposal of certain assets and the write-down of other assets. Amount for the year ended March 31, 2017 primarily relates to losses from the sale of certain assets, including excess pipe.

Goodwill

Goodwill	12 Months Ended
	Mar. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The following table summarizes changes in goodwill by segment for the periods indicated (in thousands): Crude Oil Water Liquids Refined Total (in thousands) Balances at March 31, 2017 $ 579,846 $ 424,270 $ 266,046 $ 17,050 $ 1,287,212 Revisions to acquisition accounting — 195 — — 195 Impairment — — (116,877 ) — (116,877 ) Balances at March 31, 2018 579,846 424,465 149,169 17,050 1,170,530 Acquisitions (Note 4) — 74,189 20,472 — 94,661 Disposals (Note 16) — (88,515 ) — — (88,515 ) Impairment — — (66,220 ) — (66,220 ) Balances at March 31, 2019 $ 579,846 $ 410,139 $ 103,421 $ 17,050 $ 1,110,456 Amounts in the table above do not include goodwill that was allocated to TPSL and Gas Blending, as the amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). Fiscal Year 2019 Goodwill Impairment Assessment Due to the continued decrease in demand for natural gas liquid storage and the resulting decline in revenues and earnings as compared to actual and projected results, we tested the goodwill within our natural gas liquids salt cavern storage reporting unit (“Sawtooth reporting unit”), which is part of our Liquids segment, for impairment at January 1, 2019. We estimated the fair value of our Sawtooth reporting unit based on the income approach, also known as the discounted cash flow method, which utilizes the present value of future expected cash flows to estimate the fair value. The future cash flows of our Sawtooth reporting unit were projected based upon estimates as of the test date of future revenues, operating expenses and cash outflows necessary to support these cash flows, including working capital and maintenance capital expenditures. We also considered expectations regarding: (i) expected storage volumes, which are assumed to increase in the coming years due to increased production of natural gas liquids, (ii) expected propane and butane prices, (iii) expected rental fees and (iv) the addition of storing refined products (which we acquired as part of the sale of a portion of the reporting unit (see Note 16 ). We assumed that commodity prices would be flat through the duration of the model and an average increase of approximately 7% increase in rental fees per year starting in April 2020, and held such prices and fees flat for periods in our model beyond our 2024 fiscal year. For expenses, we assumed an increase consistent with the increase in storage volumes, and maintenance capital was held flat throughout the model. The discount rate used in our discounted cash flow method was a risk adjusted weighted average cost of capital calculated as of January 1, 2019 of approximately 13.1% . The discounted cash flow results indicated that the estimated fair value of our Sawtooth reporting unit was less than its carrying value by approximately 35.2% at January 1, 2019. During the three months ended March 31, 2019, we recorded a goodwill impairment charge of $66.2 million , which was a write-off of the remaining goodwill within the Sawtooth reporting unit. The goodwill impairment charge was recorded within loss (gain) on disposal or impairment of assets, net , in our consolidated statement of operations. We performed a qualitative assessment as of January 1, 2019 to determine whether it was more likely than not that the fair value of each reporting unit was greater than the carrying value of the reporting unit. Based on these qualitative assessments, we determined that the fair value of each of these reporting units was more likely than not greater than the carrying value of the reporting units, other than the Sawtooth reporting unit as previously described. Fiscal Year 2018 Goodwill Impairment Assessment Due to the decreased demand for natural gas liquid storage and resulting decline in revenues and earnings as compared to actual and projected results of prior and future periods, we tested the goodwill within our Sawtooth reporting unit, which is part of our Liquids segment, for impairment at September 30, 2017. We estimated the fair value of our Sawtooth reporting unit based on the income approach, also known as the discounted cash flow method, which utilizes the present value of future expected cash flows to estimate the fair value. The future cash flows of our Sawtooth reporting unit were projected based upon estimates as of the test date of future revenues, operating expenses and cash outflows necessary to support these cash flows, including working capital and maintenance capital expenditures. We also considered expectations regarding: (i) expected storage volumes, which are assumed to increase in the coming years due to increased production of natural gas liquids, (ii) expected propane and butane prices and (iii) expected rental fees. We assumed a 2% per year increase in commodity prices and a 4% increase in rental fees per year starting in April 2018, and held such prices and fees flat for periods in our model beyond our 2023 fiscal year. For expenses, we assumed an increase consistent with the increase in storage volumes, and maintenance capital was held flat throughout the model. The discount rate used in our discounted cash flow method was a risk adjusted weighted average cost of capital calculated as of September 30, 2017 of 12% . The discounted cash flow results indicated that the estimated fair value of our Sawtooth reporting unit was less than its carrying value by approximately 32% at September 30, 2017. During the three months ended September 30, 2017, we recorded a goodwill impairment charge of $116.9 million , which was recorded within loss (gain) on disposal or impairment of assets, net , in our consolidated statement of operations. At September 30, 2017, our Sawtooth reporting unit had a goodwill balance of $66.2 million . In Note 16 , we discuss a transaction in which we formed a joint venture which included our Sawtooth salt dome storage facility. As a result of this transaction, we tested the goodwill of our Sawtooth reporting unit, immediately prior to the closing of this transaction, for impairment. As of March 30, 2018, our Sawtooth reporting unit had a goodwill balance of $66.2 million . Similar to the analysis we performed as of September 30, 2017, as discussed above, we estimated the fair value of our Sawtooth reporting unit based on the income approach, also known as the discounted cash flow method, which utilizes the present value of future expected cash flows to estimate the fair value. The future cash flows of our Sawtooth reporting unit were projected based upon estimates as of the test date of future revenues, operating expenses and cash outflows necessary to support these cash flows, including working capital and maintenance capital expenditures. We also considered expectations regarding: (i) expected storage volumes, which are assumed to increase in the coming years due to increased production of natural gas liquids, (ii) expected propane and butane prices and (iii) expected rental fees. We assumed a 2% per year increase in commodity prices and a 4% increase in rental fees per year starting in April 2018, and held such prices and fees flat for periods in our model beyond our 2023 fiscal year. For expenses, we assumed an increase consistent with the increase in storage volumes, and maintenance capital was held flat throughout the model. The discount rate used in our discounted cash flow method was a risk adjusted weighted average cost of capital calculated as of March 30, 2018 of 12.4% . The discounted cash flow results indicated that the estimated fair value of our Sawtooth reporting unit was greater than its carrying value by approximately 2% at March 30, 2018. Our estimated fair value is predicated upon management’s assumption of the growth in the production of natural gas liquids and the decline in the use of railcars to store natural gas liquids. We used these assumptions to estimate the demand for storage at our facility and the revenue generated by customers reserving capacity at our facility. Due to the current volatility in commodity prices and the excess railcars currently in the market, we believe it is reasonably possible that the need for underground storage we estimate in our model does not materialize, such that our estimate of fair value could change and result in further impairment of the goodwill in our Sawtooth reporting unit. We performed a qualitative assessment as of January 1, 2018 to determine whether it was more likely than not that the fair value of each reporting unit was greater than the carrying value of the reporting unit. Based on these qualitative assessments, we determined that the fair value of each of these reporting units was more likely than not greater than the carrying value of the reporting units, other than the Sawtooth reporting unit as previously described. Fiscal Year 2017 Goodwill Impairment Assessment We performed a qualitative assessment as of January 1, 2017 to determine whether it was more likely than not that the fair value of each reporting unit was greater than the carrying value of the reporting unit. Based on these qualitative assessments, we determined that the fair value of each of these reporting units was more likely than not greater than the carrying value of the reporting units. Fiscal Year 2016 Goodwill Impairment Assessment As discussed previously, during the three months ended June 30, 2016, we finalized our goodwill impairment analysis of our Water Solutions reporting unit, with the assistance of a third party valuation firm. As a result of finalizing our analysis, we determined that we needed to reverse $124.7 million of the previously recorded goodwill impairment estimate of $380.2 million recorded during the year ended March 31, 2016. The adjustment was due primarily to the change in the fair value of our customer relationship intangible assets. With the assistance of the third party valuation firm, inputs such as revenue growth rates and attrition rates related to existing customers were refined to better correlate with our historical revenue growth and attrition rates of our existing customers in our Water Solutions reporting unit. This change resulted in a lower fair value allocated to customer relationships and higher value to goodwill than in our preliminary calculation. We recorded the adjustment within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations.

Intangible Assets

Intangible Assets	12 Months Ended
	Mar. 31, 2019
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets Our intangible assets consist of the following at the dates indicated: March 31, 2019 March 31, 2018 Description Amortizable Lives Gross Carrying Amount Accumulated Amortization Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 742,832 $ (369,983 ) $ 372,849 $ 718,764 $ (328,666 ) $ 390,098 Customer commitments 10 310,000 (74,917 ) 235,083 310,000 (43,917 ) 266,083 Pipeline capacity rights 30 7,799 (1,387 ) 6,412 7,799 (1,127 ) 6,672 Rights-of-way and easements 1 - 40 73,409 (4,509 ) 68,900 63,995 (3,214 ) 60,781 Water rights 14 64,868 (3,018 ) 61,850 — — — Executory contracts and other agreements 3 - 30 47,230 (17,212 ) 30,018 42,919 (15,424 ) 27,495 Non-compete agreements 2 - 32 12,723 (2,570 ) 10,153 5,465 (706 ) 4,759 Debt issuance costs (1) 5 42,345 (29,521 ) 12,824 40,992 (24,593 ) 16,399 Total amortizable 1,301,206 (503,117 ) 798,089 1,189,934 (417,647 ) 772,287 Non-amortizable: Trade names 2,800 — 2,800 2,800 — 2,800 Total $ 1,304,006 $ (503,117 ) $ 800,889 $ 1,192,734 $ (417,647 ) $ 775,087 (1) Includes debt issuance costs related to the Revolving Credit Facility (as defined herein). Debt issuance costs related to fixed-rate notes are reported as a reduction of the carrying amount of long-term debt. Amounts in the table above do not include intangible assets and accumulated amortization related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include intangible assets and accumulated amortization related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). The weighted-average remaining amortization period for intangible assets is approximately 11.4 years . Write off of Intangible Assets During the year ended March 31, 2018 , we wrote off $1.8 million related to the non-compete agreement which was terminated as part of our acquisition of the remaining interest in NGL Solids Solutions, LLC. In connection with the amendment and restatement of the Credit Agreement (as defined herein) in February 2017, we wrote off $4.5 million of deferred debt issuance costs. During the year ended March 31, 2017 , we wrote-off $5.2 million related to the value of an indefinite-lived trade name intangible asset in conjunction with finalizing our goodwill impairment analysis. In addition, as a result of terminating the development agreement in the Water Solutions segment in June 2016 (see Note 16 ), we incurred a loss of $5.8 million to write off the water facility development agreement. The losses for the years ended March 31, 2018 and 2017 are reported within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. Amortization expense is as follows for the periods indicated: Year Ended March 31, Recorded In 2019 2018 2017 (in thousands) Depreciation and amortization $ 110,458 $ 108,444 $ 89,765 Cost of sales 486 966 1,994 Interest expense 4,928 4,568 4,471 Total $ 115,872 $ 113,978 $ 96,230 Amounts in the table above do not include amortization expense related to TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ). Expected amortization of our intangible assets is as follows (in thousands): Year Ending March 31, 2020 $ 116,626 2021 104,512 2022 91,674 2023 83,654 2024 77,514 Thereafter 324,109 Total $ 798,089

Long-Term Debt

Long-Term Debt	12 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Our long-term debt consists of the following at the dates indicated: March 31, 2019 March 31, 2018 Face Unamortized Book Face Unamortized Book (in thousands) Revolving credit facility: Expansion capital borrowings $ 275,000 $ — $ 275,000 $ — $ — $ — Working capital borrowings 896,000 — 896,000 969,500 — 969,500 Senior unsecured notes: 5.125% Notes due 2019 ("2019 Notes") — — — 353,424 (1,653 ) 351,771 6.875% Notes due 2021 ("2021 Notes") — — — 367,048 (4,499 ) 362,549 7.500% Notes due 2023 ("2023 Notes") 607,323 (6,916 ) 600,407 615,947 (8,542 ) 607,405 6.125% Notes due 2025 ("2025 Notes") 389,135 (5,092 ) 384,043 389,135 (5,951 ) 383,184 Other long-term debt 5,331 — 5,331 5,977 — 5,977 2,172,789 (12,008 ) 2,160,781 2,701,031 (20,645 ) 2,680,386 Less: Current maturities 648 — 648 646 — 646 Long-term debt $ 2,172,141 $ (12,008 ) $ 2,160,133 $ 2,700,385 $ (20,645 ) $ 2,679,740 (1) Debt issuance costs related to the Revolving Credit Facility are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt. Amounts in the table above do not include long-term debt related to our former Retail Propane segment, as these amounts have been classified as liabilities held for sale within our March 31, 2018 consolidated balance sheet (see Note 17 ). Amortization expense for debt issuance costs related to long-term debt in the table above was $4.3 million , $6.1 million and $3.3 million during the years ended March 31, 2019 , 2018 and 2017 . Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2020 $ 2,371 2021 2,367 2022 2,367 2023 2,367 2024 1,744 Thereafter 792 Total $ 12,008 Credit Agreement We are party to a $1.765 billion credit agreement (the “Credit Agreement”) with a syndicate of banks. As of March 31, 2019 , the Credit Agreement includes a revolving credit facility to fund working capital needs, which had a capacity of $1.250 billion for cash borrowings and letters of credit (the “Working Capital Facility”), and a revolving credit facility to fund acquisitions and expansion projects, which had a capacity of $515.0 million (the “Expansion Capital Facility,” and together with the Working Capital Facility, the “Revolving Credit Facility”). The Revolving Credit Facility allows us to reallocate amounts between the Expansion Capital Facility and Working Capital Facility. We had letters of credit of $143.4 million o n the Working Capital Facility at March 31, 2019 . The capacity under the Working Capital Facility may be limited by a “borrowing base” (as defined in the Credit Agreement) which is calculated based on the value of certain working capital items at any point in time. The commitments under the Credit Agreement expire on October 5, 2021. We have the right to prepay outstanding borrowings under the Credit Agreement without incurring any penalties, and prepayments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings. The Credit Agreement is secured by substantially all of our assets. At March 31, 2019 , the borrowings under the Credit Agreement had a weighted average interest rate of 4.39% , calculated as the weighted average LIBOR rate of 2.49% plus a margin of 1.75% for LIBOR borrowings and the prime rate of 5.50% plus a margin of 0.75% on alternate base rate borrowings. At March 31, 2019 , the interest rate in effect on letters of credit was 1.75% . Commitment fees are charged at a rate ranging from 0.375% to 0.50% on any unused capacity. On July 5, 2018, we amended the Credit Agreement. In the amendment, the lenders consented to, subject to the consummation of the Retail Propane disposition, release NGL Propane, LLC and its wholly-owned subsidiaries from its guaranty and other obligations under the loan documents, among other things. In return, the Partnership agreed to use the net proceeds from the Retail Propane disposition to pay down existing indebtedness no later than five business days after the consummation of the Retail Propane disposition. On February 6, 2019 , we amended the Credit Agreement, to, among other things, reset the basket for the repurchase of common units with a limit of $150 million in aggregate during the remaining term of the Credit Agreement, not to exceed $50 million per fiscal quarter, so long as, both immediately before and after giving pro forma effect to the repurchases, the Partnership’s Leverage Ratio (as defined in the Credit Agreement) is less than 3.25x and Revolving Availability (also as defined in the Credit Agreement) is greater than or equal to $200 million. In addition, the amendment decreases the Maximum Total Leverage Indebtedness Ratio beginning September 30, 2019 with a further decrease beginning March 31, 2020 (as presented in the table below), and amends the defined term “Consolidated EBITDA” to exclude the “Gavilon Energy EPA Settlement” (as defined in the Credit Agreement) solely for the two quarters ending December 31, 2018 and March 31, 2019. The following table summarizes the debt covenant levels specified in the Credit Agreement as of March 31, 2019 (as modified on February 6, 2019): Senior Secured Interest Total Leverage Period Beginning Leverage Ratio (1) Leverage Ratio (1) Coverage Ratio (2) Indebtedness Ratio (1) March 31, 2019 4.50 3.25 2.75 6.50 September 30, 2019 4.50 3.25 2.75 6.25 March 31, 2020 and thereafter 4.50 3.25 2.75 6.00 (1) Represents the maximum ratio for the period presented. (2) Represents the minimum ratio for the period presented. At March 31, 2019 , our leverage ratio was approximately 2.63 to 1 , our senior secured leverage ratio was approximately 0.58 to 1 , our interest coverage ratio was approximately 3.70 to 1 and our total leverage indebtedness ratio was approximately 4.48 to 1 . The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency. We were in compliance with the covenants under the Credit Agreement at March 31, 2019 . Senior Secured Notes On June 19, 2012, we entered into the Note Purchase Agreement (as amended, the “Senior Secured Notes Purchase Agreement”) whereby we issued $250.0 million of senior secured notes in a private placement (the “Senior Secured Notes”). The Senior Secured Notes paid interest at a fixed rate of 6.65% which was payable quarterly. The Senior Secured Notes were required to be repaid in semi-annual installments of $25.0 million beginning on December 19, 2017 and ending on the maturity date of June 19, 2022. We had the option to prepay outstanding principal, although we would incur a prepayment penalty. On December 29, 2017, we repurchased all of the remaining outstanding Senior Secured Notes. See below for the details related to the repurchase. Repurchases The following table summarizes repurchases of Senior Secured Notes for the period indicated: Year Ended March 31, 2018 (in thousands) Senior Secured Notes Notes repurchased $ 230,500 Cash paid (excluding payments of accrued interest) $ 250,179 Loss on early extinguishment of debt (1) $ (23,971 ) (1) Loss on the early extinguishment of debt for the Senior Secured Notes during the year ended March 31, 2018 is inclusive of the write off of debt issuance costs of $4.3 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Prior to the December 29, 2017 repurchase of all the remaining outstanding Senior Secured Notes, we made a semi-annual principal installment payment of $19.5 million on December 19, 2017. Senior Unsecured Notes The senior unsecured notes include, as defined below, the 2019 Notes, 2021 Notes, 2023 Notes, 2025 Notes and 2026 Notes (collectively, the “Senior Unsecured Notes”). The Partnership and NGL Energy Finance Corp. are co-issuers of the Senior Unsecured Notes, and the obligations under the Senior Unsecured Notes are fully and unconditionally guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The indentures governing the Senior Unsecured Notes contain various customary covenants, including, (i) pay distributions on, purchase or redeem our common equity or purchase or redeem our subordinated debt, (ii) incur or guarantee additional indebtedness or issue preferred units, (iii) create or incur certain liens, (iv) enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us, (v) consolidate, merge or transfer all or substantially all of our assets, and (vi) engage in transactions with affiliates. Our obligations under the Senior Unsecured Notes may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency. Issuances On July 9, 2014, we issued $400.0 million of 5.125% Senior Unsecured Notes Due 2019 (the “2019 Notes”). Interest is payable on January 15 and July 15 of each year. The 2019 Notes were redeemed on March 15, 2019. See further discussion below. On October 16, 2013, we issued $450.0 million of 6.875% Senior Unsecured Notes Due 2021 (the “2021 Notes”). Interest is payable on April 15 and October 15 of each year. The 2021 Notes were redeemed on October 16, 2018. See further discussion below. On October 24, 2016, we issued $700.0 million of 7.50% Senior Unsecured Notes Due 2023 (the “2023 Notes”). Interest is payable on May 1 and November 1 of each year. The registration of the 2023 Notes became effective on July 11, 2017. The 2023 Notes mature on November 1, 2023. On February 22, 2017, we issued $500.0 million of 6.125% Senior Unsecured Notes Due 2025 (the “2025 Notes”). Interest is payable on March 1 and September 1 of each year. The registration of the 2025 Notes became effective on July 11, 2017. The 2025 Notes mature on March 1, 2025. On April 9, 2019, we issued $450.0 million of 7.50% Senior Unsecured Notes Due 2026 (the “2026 Notes”) in a private placement. The 2026 Notes bear interest, which is payable on April 15 and October 15 of each year, beginning on October 15, 2019. We received net proceeds of $441.8 million , after the initial purchasers’ discount of $6.8 million and offering costs of $1.5 million . The 2026 Notes mature on April 15, 2026 . The Partnership and NGL Energy Finance Corp. are co-issuers of the 2026 Notes, and the obligations under the 2026 Notes are fully and unconditionally guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The indenture governing the 2026 Notes contains various customary covenants, including, (i) pay distributions on, purchase or redeem our common equity or purchase or redeem our subordinated debt, (ii) incur or guarantee additional indebtedness or issue preferred units, (iii) create or incur certain liens, (iv) enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us, (v) consolidate, merge or transfer all or substantially all of our assets, and (vi) engage in transactions with affiliates. Our obligations under the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency. We have the option to redeem all or a portion of the 2026 Notes at any time on or after April 15, 2022 at fixed redemption prices beginning at 103.750% on such date and declining annually and ratably to par for redemptions occurring on or after April 15, 2024 plus accrued and unpaid interest. At any time prior to April 15, 2022, we may redeem all or a portion of the 2026 Notes, at a redemption price equal to the “make whole price” specified in the indenture, plus accrued and unpaid interest. In connection with the closing of the offering of the 2026 Notes, the Partnership entered into a registration rights agreement (the “Registration Rights Agreement”). Under the Registration Rights Agreement, the Partnership agreed to file a registration statement with the Securities and Exchange Commission (“SEC”) so that holders can exchange the 2026 Notes for registered notes that have substantially identical terms as the 2026 Notes and evidence the same indebtedness as the 2026 Notes. In addition, the subsidiary guarantors agreed to exchange the guarantee related to the 2026 Notes for a registered guarantee having substantially the same terms as the original guarantees. The Partnership is obligated to use commercially reasonable efforts to file an exchange offer registration statement with respect to the exchange notes and exchange guarantees and cause such exchange offer registration statement to become effective on or prior to 365 days after the closing of this offering. If the Partnership fails to satisfy this obligation, it will be required to pay to the holders of the 2026 Notes liquidated damages in an amount equal 0.25% per annum on the principal amount of the 2026 Notes held by such holder during the 90-day period immediately following the occurrence of such registration default, and such amount shall increase by 0.25% per annum at the end of such 90-day period. Redemptions The following table summarizes redemptions of Senior Unsecured Notes for the period indicated: Year Ended March 31, 2019 (in thousands) 2019 Notes (1) Notes redeemed $ 328,005 Cash paid (excluding payments of accrued interest) $ 329,719 Loss on early extinguishment of debt $ (2,113 ) 2021 Notes (2) Notes redeemed $ 367,048 Cash paid (excluding payments of accrued interest) $ 373,358 Loss on early extinguishment of debt $ (10,130 ) (1) On March 15, 2019, we redeemed all of the remaining outstanding 2019 Notes. Loss on the early extinguishment of debt for the 2019 Notes during the year ended March 31, 2019 is inclusive of the write off of debt issuance costs of $0.4 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) On October 16, 2018, we redeemed all of the remaining outstanding 2021 Notes. Loss on the early extinguishment of debt for the 2021 Notes during the year ended March 31, 2019 is inclusive of the write off of debt issuance costs of $3.8 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Repurchases The following table summarizes repurchases of Senior Unsecured Notes for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) 2019 Notes Notes repurchased $ 25,419 $ 26,034 $ 9,009 Cash paid (excluding payments of accrued interest) $ 25,406 $ 26,002 $ 7,099 (Loss) gain on early extinguishment of debt (1) $ (34 ) $ (140 ) $ 1,759 2021 Notes Notes repurchased $ — $ — $ 21,241 Cash paid (excluding payments of accrued interest) $ — $ — $ 14,094 Gain on early extinguishment of debt (2) $ — $ — $ 6,748 2023 Notes Notes repurchased $ 8,624 $ 84,053 $ — Cash paid (excluding payments of accrued interest) $ 8,575 $ 83,967 $ — Loss on early extinguishment of debt (3) $ (63 ) $ (1,136 ) $ — 2025 Notes Notes repurchased $ — $ 110,865 $ — Cash paid (excluding payments of accrued interest) $ — $ 107,050 $ — Gain on early extinguishment of debt (4) $ — $ 2,046 $ — (1) (Loss) gain on early extinguishment of debt for the 2019 Notes during the years ended March 31, 2019, 2018 and 2017 is inclusive of the write off of debt issuance costs of less than $0.1 million $0.2 million and $0.2 million , respectively. The (loss) gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) Gain on early extinguishment of debt for the 2021 Notes during the year ended March 31, 2017 is inclusive of the write off of debt issuance costs of $0.4 million . The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (3) Loss on early extinguishment of debt for the 2023 Notes during the years ended March 31, 2019 and 2018 is inclusive of the write off of debt issuance costs of $0.1 million and $1.2 million , respectively. The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (4) Gain on early extinguishment of debt for the 2025 Notes during the year ended March 31, 2018 is inclusive of the write off of debt issuance costs of $1.8 million . The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Compliance At March 31, 2019 , we were in compliance with the covenants under all of the Senior Unsecured Notes indentures. Other Long-Term Debt We have other notes payable related to equipment financing. The interest rates on these instruments range from 4.13% to 7.10% per year and have an aggregate principal balance of $5.3 million at March 31, 2019. Equipment loans totaling $41.7 million were paid off on March 30, 2017, resulting in a loss on the early extinguishment of debt of $1.6 million , which was net of $0.1 million of debt issuance costs and $1.5 million of prepayment penalties. The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Debt Maturity Schedule The scheduled maturities of our long-term debt are as follows at March 31, 2019 : Year Ending March 31, Revolving Senior Unsecured Notes Other Long-Term Debt Total (in thousands) 2020 $ — $ — $ 648 $ 648 2021 — — 4,683 4,683 2022 1,171,000 — — 1,171,000 2023 — — — — 2024 — 607,323 — 607,323 Thereafter — 389,135 — 389,135 Total $ 1,171,000 $ 996,458 $ 5,331 $ 2,172,789

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Contingencies In August 2015, LCT Capital, LLC (“LCT”) filed a lawsuit against NGL Energy Holdings LLC (the “GP”) and the Partnership seeking payment for investment banking services relating to the purchase of TransMontaigne Inc. and related assets in July 2014. After pre-trial rulings, LCT was limited to pursuing claims of (i) quantum meruit (the value of the services rendered by LCT) and (ii) fraudulent misrepresentation against the defendants. Following a jury trial conducted in Delaware state court from July 23, 2018 through August 1, 2018, the jury returned a verdict consisting of an award of $4.0 million for quantum meruit and $29.0 million for fraudulent misrepresentation, subject to statutory interest. The GP and the Partnership contend that the jury verdict, at least in respect of fraudulent misrepresentation, is not supportable by either controlling law or the evidentiary record. Both defendants have a pending motion for judgment as a matter of law on the fraudulent misrepresentation claim and plan to file post-verdict motions as appropriate before the trial court, and, if need be, will file an appeal to the Delaware Supreme Court. It is our position that the awards, even if they each stand, are not cumulative. Any allocation of the ultimate verdict award between the GP and the Partnership will be made by the board of directors once all information is available to it and after the post-trial and any appellate process has run its course and the verdict is final as a matter of law. Because the Partnership is a named defendant in the lawsuit, and any judgment ultimately awarded would be joint and several with the GP, we have determined that it is probable that the Partnership could be liable for a portion of this judgment. At this time, we believe the amount that could be allocated to the Partnership would not be material as it is estimated to be less than $4.0 million . As of March 31, 2019 , we have accrued $2.5 million related to this matter. We are party to various claims, legal actions, and complaints arising in the ordinary course of business. In the opinion of our management, the ultimate resolution of these claims, legal actions, and complaints, after consideration of amounts accrued, insurance coverage, and other arrangements, is not expected to have a material adverse effect on our consolidated financial position, results of operations or cash flows. However, the outcome of such matters is inherently uncertain, and estimates of our liabilities may change materially as circumstances develop. Environmental Matters At March 31, 2019 , we have an environmental liability, measured on an undiscounted basis, of $2.5 million , which is recorded within accrued expenses and other payables in our consolidated balance sheet. Our operations are subject to extensive federal, state, and local environmental laws and regulations. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our business, and there can be no assurance that we will not incur significant costs. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations, could result in substantial costs. Accordingly, we have adopted policies, practices, and procedures in the areas of pollution control, product safety, occupational health, and the handling, storage, use, and disposal of hazardous materials designed to prevent material environmental or other damage, and to limit the financial liability that could result from such events. However, some risk of environmental or other damage is inherent in our business. In 2015, as previously disclosed, the U.S. Environmental Protection Agency (“EPA”) informed NGL Crude Logistics, LLC, formerly known as Gavilon, LLC (“Gavilon Energy”), of alleged violations that occurred in 2011 by Gavilon Energy of the Clean Air Act’s renewable fuel standards regulations (prior to its acquisition by us in December 2013). On October 4, 2016, the U.S. Department of Justice, acting at the request of the EPA, filed a civil complaint in the Northern District of Iowa against Gavilon Energy and one of its then suppliers, Western Dubuque Biodiesel LLC (“Western Dubuque”). Consistent with the earlier allegations by the EPA, the civil complaint related to transactions between Gavilon Energy and Western Dubuque and the generation of biodiesel renewable identification numbers (“RINs”) sold by Western Dubuque to Gavilon Energy in 2011. On December 19, 2016, we filed a motion to dismiss the complaint. On January 9, 2017, the EPA filed an amended complaint. The amended complaint seeks an order declaring Western Dubuque’s RINs invalid and requiring the defendants to retire an equivalent number of valid RINs and that the defendants pay statutory civil penalties. On January 23, 2017, we filed a motion to dismiss the amended complaint. On May 24, 2017, the court denied our motion to dismiss. Subsequently, the EPA filed a second amended complaint seeking an order declaring Western Dubuque’s RINs invalid, an order requiring us to retire an equivalent number of valid RINs and an award against us of statutory civil penalties. In May 2018, the parties completed briefing on cross-motions for summary judgment concerning liability issues in the case. On July 3, 2018, the Court denied our summary judgment motion and largely granted the plaintiff’s two summary judgment motions on liability. On July 19, 2018, Gavilon Energy reached an agreement in principle with the EPA regarding the terms of a settlement of the case, which was memorialized in a consent decree lodged to the Court on September 27, 2018. Such terms will result in Gavilon Energy paying cash of $25.0 million and retiring 36 million RINs, over a twelve-month period. The consent decree was approved by the Court on November 8, 2018. The consent decree resolves all matters between Gavilon Energy and the EPA in connection with the above-described complaint. During the year ended March 31, 2019 , we paid the EPA $12.5 million and retired all 36 million RINs. As of March 31, 2019 , we have an accrual, which is included within accrued expenses and other payables in our consolidated balance sheet, of $12.5 million . Asset Retirement Obligations We have contractual and regulatory obligations at certain facilities for which we have to perform remediation, dismantlement, or removal activities when the assets are retired. Our liability for asset retirement obligations is discounted to present value. To calculate the liability, we make estimates and assumptions about the retirement cost and the timing of retirement. Changes in our assumptions and estimates may occur as a result of the passage of time and the occurrence of future events. The following table summarizes changes in our asset retirement obligation, which is reported within other noncurrent liabilities in our consolidated balance sheets (in thousands): Balance at March 31, 2017 $ 8,181 Liabilities incurred 592 Liabilities assumed in acquisitions 21 Liabilities settled (549 ) Accretion expense 888 Balance at March 31, 2018 9,133 Liabilities incurred 586 Liabilities assumed in acquisitions 438 Liabilities associated with disposed assets (1) (585 ) Liabilities settled (546 ) Accretion expense 697 Balance at March 31, 2019 $ 9,723 (1) This amount primarily relates to the sales of our Bakken and South Pecos water disposal businesses (see Note 16 ). In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. However, the fair value of the asset retirement obligation cannot currently be reasonably estimated because the settlement dates are indeterminable. We will record an asset retirement obligation for these assets in the periods in which settlement dates are reasonably determinable. Operating Leases We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, railcars, and equipment. The following table summarizes future minimum lease payments under these agreements at March 31, 2019 (in thousands): Year Ending March 31, 2020 $ 78,348 2021 60,417 2022 43,259 2023 29,252 2024 18,341 Thereafter 41,845 Total $ 271,462 Amounts in the table above do not include future minimum lease payments related to Mid-Con, Gas Blending and TPSL as Mid-Con, Gas Blending and TPSL have been classified as discontinued operations in our consolidated statements of operations (see Note 1 and Note 17 ). Rental expense relating to operating leases was $91.6 million , $111.3 million , and $114.6 million during the years ended March 31, 2019 , 2018 and 2017 , respectively. Amounts above do not include rental expense related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ). Pipeline Capacity Agreements We have executed noncancelable agreements with crude oil pipeline operators, which guarantee us minimum monthly shipping capacity on the pipelines. As a result, we are required to pay the minimum shipping fees if actual shipments are less than our allotted capacity. Under certain agreements we have the ability to recover minimum shipping fees previously paid if our shipping volumes exceed the minimum monthly shipping commitment during each month remaining under the agreement, with some contracts containing provisions that allow us to continue shipping up to six months after the maturity date of the contract in order to recapture previously paid minimum shipping delinquency fees. We currently have an asset recorded in other noncurrent assets in our consolidated balance sheet for minimum shipping fees paid in both the current and previous periods that are expected to be recovered in future periods by exceeding the minimum monthly volumes (see Note 2 ). The future minimum throughput payments under these agreements at March 31, 2019 are $43.2 million . The payments for these agreements will be completed at the end of fiscal year 2020. Of the total future minimum throughput payments, a third party has agreed to assume all rights and privileges and to be fully responsible for any minimum shipping fees due for actual shipments that are less than our allotted capacity related to $30.0 million of the fiscal year 2020 amount under a definitive agreement we signed during the three months ended June 30, 2018 (see Note 13 ). Construction Commitments At March 31, 2019 , we had construction commitments of $29.7 million . Sales and Purchase Contracts We have entered into product sales and purchase contracts for which we expect the parties to physically settle and deliver the inventory in future periods. At March 31, 2019 , we had the following commodity purchase commitments (in thousands): Crude Oil (1) Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Purchase Commitments: 2020 $ 60,227 1,040 $ 5,033 7,545 2021 — — 265 378 Total $ 60,227 1,040 $ 5,298 7,923 Index-Price Commodity Purchase Commitments: 2020 $ 1,703,112 30,363 $ 564,013 1,023,998 2021 526,420 10,227 1,199 2,152 2022 411,071 8,264 — — 2023 269,990 5,482 — — 2024 200,022 4,110 — — Total $ 3,110,615 58,446 $ 565,212 1,026,150 (1) Our crude oil index-price purchase commitments exceed our crude oil index-price sales commitments (presented below) due primarily to our long-term purchase commitments for crude oil that we purchase and ship on the Grand Mesa Pipeline. As these purchase commitments are deliver-or-pay contracts, whereby our counterparty is required to pay us for any volumes not delivered, we have not entered into corresponding long-term sales contracts for volumes we may not receive. At March 31, 2019 , we had the following commodity sale commitments (in thousands): Crude Oil Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Sale Commitments: 2020 $ 63,759 1,090 $ 45,626 52,766 2021 — — 1,395 1,580 2022 — — 86 100 Total $ 63,759 1,090 $ 47,107 54,446 Index-Price Commodity Sale Commitments: 2020 $ 1,240,074 20,500 $ 594,877 778,454 2021 — — 1,634 2,183 Total $ 1,240,074 20,500 $ 596,511 780,637 We account for the contracts shown in the tables above using the normal purchase and normal sale election . Under this accounting policy election, we do not record the physical contracts at fair value at each balance sheet date; instead, we record the purchase or sale at the contracted value once the delivery occurs. Contracts in the tables above may have offsetting derivative contracts (described in Note 11 ) or inventory positions (described in Note 2 ). Certain other forward purchase and sale contracts do not qualify for the normal purchase and normal sale election. These contracts are recorded at fair value in our consolidated balance sheet and are not included in the tables above. These contracts are included in the derivative disclosures in Note 11 , and represent $8.6 million of our prepaid expenses and other current assets and $4.9 million of our accrued expenses and other payables at March 31, 2019 .

Equity

Equity	12 Months Ended
	Mar. 31, 2019
Equity [Abstract]
Equity	Equity Partnership Equity The Partnership’s equity consists of a 0.1% general partner interest and a 99.9% limited partner interest, which consists of common units. Our general partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its 0.1% general partner interest. Our general partner is not required to guarantee or pay any of our debts or obligations. General Partner Contributions In connection with the issuance of common units for the vesting of restricted units and warrants that were exercised for common units during the year ended March 31, 2019 , we issued 3,039 notional units to our general partner for less than $0.1 million in order to maintain its 0.1% interest in us. In connection with the issuance of common units for the vesting of restricted units and warrants that were exercised for common units during the year ended March 31, 2018, we issued 1,294 notional units to our general partner for less than $0.1 million in order to maintain its 0.1% interest in us. In connection with the issuance of common units for the vesting of restricted units, ATM Program (as defined herein) and the equity issuance in February 2017, as discussed within this note, as well as common units issued for a retail propane acquisition during the year ended March 31, 2017, we issued 16,026 notional units to our general partner for $0.3 million in order to maintain its 0.1% interest in us. Equity Issuances On August 24, 2016, we entered into an equity distribution agreement in connection with an at-the-market program (the “ATM Program”) pursuant to which we may issue and sell up to $200.0 million of common units. This ATM Program is registered with the SEC on an effective registration statement on Form S-3. During the year ended March 31, 2017, we sold 3,321,135 common units for net proceeds of $64.4 million (net of offering costs of $0.9 million ). We did not sell any common units under the ATM Program during the years ended March 31, 2019 and 2018. As of March 31, 2019 , approximately $134.7 million remained available for sale under the ATM Program. On February 22, 2017, we completed a public offering of 10,120,000 common units. We received net proceeds of $222.5 million (net of offering costs of $11.8 million ). Common Unit Repurchase Program On August 29, 2017, the board of directors of our general partner authorized a common unit repurchase program, under which we may repurchase up to $15.0 million of our outstanding common units through December 31, 2017 from time to time in the open market or in other privately negotiated transactions . Under this program, we repurchased 1,516,848 common units for an aggregate price of $15.0 million , including commissions. This program ended on December 31, 2017. Our Distributions The following table summarizes distributions declared on our common units during the last three fiscal years: Date Declared Record Date Payment Date Amount Per Unit Amount Paid to Limited Partners Amount Paid to General Partner (in thousands) (in thousands) April 21, 2016 May 3, 2016 May 13, 2016 $ 0.3900 $ 40,626 $ 70 July 21, 2016 August 4, 2016 August 12, 2016 $ 0.3900 $ 41,146 $ 71 October 20, 2016 November 4, 2016 November 14, 2016 $ 0.3900 $ 41,907 $ 72 January 19, 2017 February 3, 2017 February 14, 2017 $ 0.3900 $ 42,923 $ 74 April 24, 2017 May 8, 2017 May 15, 2017 $ 0.3900 $ 46,870 $ 80 July 20, 2017 August 4, 2017 August 14, 2017 $ 0.3900 $ 47,460 $ 81 October 19, 2017 November 6, 2017 November 14, 2017 $ 0.3900 $ 47,000 $ 81 January 23, 2018 February 6, 2018 February 14, 2018 $ 0.3900 $ 47,223 $ 81 April 24, 2018 May 7, 2018 May 15, 2018 $ 0.3900 $ 47,374 $ 82 July 24, 2018 August 8, 2018 August 14, 2018 $ 0.3900 $ 47,600 $ 82 October 23, 2018 November 8, 2018 November 14, 2018 $ 0.3900 $ 48,260 $ 83 January 22, 2019 February 6, 2019 February 14, 2019 $ 0.3900 $ 48,373 $ 83 April 24, 2019 May 7, 2019 May 15, 2019 $ 0.3900 $ 49,127 $ 85 Class A Convertible Preferred Units On April 21, 2016, we entered into a private placement agreement to issue $200 million of 10.75% Class A Convertible Preferred Units (“Class A Preferred Units”) to Oaktree Capital Management L.P. and its co-investors (“Oaktree”). On June 23, 2016, the private placement agreement was amended to increase the aggregate principal amount from $200 million to $240 million . We received net proceeds of $235.0 million (net of offering costs of $5.0 million ) in connection with the issuance of 19,942,169 Class A Preferred Units and 4,375,112 warrants. We pay a cumulative, quarterly distribution in arrears at an annual rate of 10.75% on the Class A Preferred Units to the extent declared by the board of directors of our general partner. To the extent declared, such distributions will be paid for each such quarter within 45 days after each quarter end. The following table summarizes distributions declared on our Class A Preferred Units during the last three fiscal years: Date Declared Payment Date Amount Paid to Class A (in thousands) July 21, 2016 August 12, 2016 $ 1,795 October 20, 2016 November 14, 2016 $ 6,449 January 19, 2017 February 14, 2017 $ 6,449 April 24, 2017 May 15, 2017 $ 6,449 July 20, 2017 August 14, 2017 $ 6,449 October 19, 2017 November 14, 2017 $ 6,449 January 23, 2018 February 14, 2018 $ 6,449 April 24, 2018 May 15, 2018 $ 6,449 July 24, 2018 August 14, 2018 $ 6,449 October 23, 2018 November 14, 2018 $ 6,449 January 22, 2019 February 14, 2019 $ 6,449 April 24, 2019 May 10, 2019 $ 4,034 If the Class A Preferred Unit quarterly distribution is not made in full in cash for any quarter, the Class A Preferred Unit distribution rate will increase by one quarter of a percentage point ( 0.25% ) per year beginning with distributions for the first six -month period that a payment default is in effect, and will further increase by an additional one quarter of a percentage point ( 0.25% ) beginning with distributions for the next six -month period during which a payment default remains in effect. The deficiency rate shall not exceed 11.25% per year; as long as the default is occurring, the amount of accrued but unpaid Class A Preferred Unit quarterly distributions shall increase at an annual rate of 10.75% , compounded quarterly, until paid in full. The Class A Preferred Units have no mandatory redemption date but are redeemable, at our election, any time after the first anniversary of the closing date. We have the right to redeem all of the outstanding Class A Preferred Units at a price per Class A Preferred Unit equal to the purchase price multiplied by the redemption multiple then in effect. The redemption multiple means (a) 140% for redemptions occurring on or after the first, but prior to the second anniversary of the closing date, (b) 115% for redemptions occurring on or after the second, but prior to the third anniversary of the closing date, (c) 110% for redemptions occurring on or after the third, but prior to the eighth anniversary of the closing date and (d) 101% for redemptions occurring on or after the eighth anniversary of the closing date. At any time after the third anniversary of the initial closing date, the Class A preferred unitholders shall have the right to convert all of the outstanding Class A Preferred Units at a price per Class A Preferred Unit equal to the purchase price multiplied by the conversion multiple then in effect, which may be settled in common units, cash or a combination, at our discretion. The conversion multiple means if our common units are trading at or above $12.035 (“the initial conversion price”), the conversion price is not adjusted. However, if the conversion price is less than the initial conversion price, the conversion price will be reset to the greater of (i) the adjusted volume weighted average price of our common units for the 15 trading days immediately preceding the third anniversary of the closing date or (ii) $5.00 . Upon a change of control of the Partnership, each Class A preferred unitholder shall have the right, at its election, to either (i) elect to have its Class A Preferred Units converted to common units; (ii) if we are the surviving entity of such change of control, it can elect to continue to hold its Class A Preferred Units; or (iii) require us to redeem its Class A Preferred Units for cash equal to (a) prior to the first anniversary of the closing date, 140% of the unit purchase price; (b) on or after the first but prior to the second anniversary of the closing date, 130% of the unit purchase price; (c) on or after the second anniversary of the closing date, 120% of the unit purchase price; and (d) thereafter, 101% of the unit purchase price. In each case, this amount will include any accrued but unpaid distributions at the redemption date. Under the private placement agreement, we are required to file within 180 days of the initial closing date a registration statement registering the resales of common units issued or to be issued upon conversion of the Class A Preferred Units or exercise of the warrants and have the registration statement declared effective within 360 days after the closing date. We are required to continue to maintain the effectiveness of the registration statement until all securities have been sold. The Partnership’s registration statement was declared effective by the SEC on November 23, 2016. The warrants have an eight year term, after which unexercised warrants will expire. The holders of the warrants may exercise one-third of the warrants from and after the first anniversary of the original issue date, another one-third of the warrants from and after the second anniversary and the final one-third of the warrants from and after the third anniversary. Upon a change of control or in the event we exercise our redemption right with respect to the Class A Preferred Units, all unvested warrants shall immediately vest and be exercisable in full. The warrants have an exercise price of $0.01 . During the year ended March 31, 2019, 228,797 warrants were exercised for common units and we received proceeds of less than $0.1 million , and we repurchased 1,229,575 unvested warrants for a total purchase price of $15.0 million on April 26, 2018. During the year ended March 31, 2018, 607,653 warrants were exercised for common units and we received proceeds of less than $0.1 million , and we repurchased 850,716 unvested warrants for a total purchase price of $10.5 million on June 23, 2017. As of March 31, 2019 , we had 1,458,371 warrants that remain outstanding, which were all exercised for common units on April 5, 2019 (see below for a further discussion). We allocated the net proceeds on a relative fair value basis to the Class A Preferred Units ( $186.4 million ), which includes the value of a beneficial conversion feature, and warrants ( $48.6 million ). As discussed below, $131.5 million of the amount allocated to the Class A Preferred Units was allocated to the intrinsic value of the beneficial conversion feature. A beneficial conversion feature is defined as a nondetachable conversion feature that is in the money at the commitment date. Per the applicable accounting guidance, we are required to allocate a portion of the proceeds allocated to the Class A Preferred Units to the beneficial conversion feature based on the intrinsic value of the beneficial conversion feature. The intrinsic value is calculated at the commitment date based on the difference between the fair value of the common units at the issuance date (number of common units issuable at conversion multiplied by the per unit value of our common units at the issuance date) and the proceeds attributed to the Class A Preferred Units. We record the accretion attributable to the beneficial conversion feature as a deemed distribution using the effective interest method over the three year period prior to the effective dates of the holders’ conversion right. Accretion for the beneficial conversion feature was $67.2 million , $18.8 million and $9.0 million for the years ended March 31, 2019 , 2018 and 2017 , respectively. As discussed above, the Class A Preferred Units are not mandatorily redeemable but are redeemable upon a change of control, which was not certain to occur at the issuance of the Class A Preferred Units. Due to the redemption being conditioned upon an event that is not certain to occur or that is not under our control, we are required to record the value allocated to the Class A Preferred Units, excluding the value of the beneficial conversion feature, between liabilities and equity (mezzanine or temporary equity) in our consolidated balance sheet. The value allocated to the warrants and the beneficial conversion feature was recorded within limited partners’ equity in our consolidated balance sheet. On April 5, 2019, we made a partial redemption of 7,468,978 of the Class A Preferred Units. The applicable Class A redemption premium on the date of redemption was $13.389 , calculated at 111.25% of $12.035 (the Class A Preferred Unit price), and the accrued but unpaid and accumulated distributions of $0.338 . The amount per Class A Preferred Unit paid to each Class A preferred unitholder was $13.727 , for a total payment of $102.5 million . On April 5, 2019, Oaktree also exercised all of its 1,458,371 warrants to purchase common units for proceeds of less than $0.1 million . On May 11, 2019, we redeemed the remaining 12,473,191 outstanding Class A Preferred Units. The applicable Class A redemption premium on the date of redemption was $13.2385 , calculated at 110% of $12.035 (the Class A Preferred Unit price), and the accrued but unpaid and accumulated distributions of $0.1437 . The amount per Class A Preferred Unit paid to each Class A preferred unitholder was $13.3822 , for a total payment of $166.9 million . In addition, we paid the Class A preferred unitholders the distribution declared for the quarter ended March 31, 2019, as noted above. Class B Preferred Units On June 13, 2017, we issued 8,400,000 of our 9.00% Class B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (“Class B Preferred Units”) representing limited partner interests at a price of $25.00 per unit for net proceeds of $202.7 million (net of the underwriters’ discount of $6.6 million and offering costs of $0.7 million ). At any time on or after July 1, 2022, we may redeem our Class B Preferred Units, in whole or in part, at a redemption price of $25.00 per Class B Preferred Unit plus an amount equal to all accumulated and unpaid distributions to, but not including, the date of redemption, whether or not declared. We may also redeem the Class B Preferred Units upon a change of control as defined in our partnership agreement. If we choose not to redeem the Class B Preferred Units, the Class B preferred unitholders may have the ability to convert the Class B Preferred Units to common units at the then applicable conversion rate. Class B preferred unitholders have no voting rights except with respect to certain matters set forth in our partnership agreement. Distributions on the Class B Preferred Units are payable on the 15th day of each January, April, July and October of each year to holders of record on the first day of each payment month. The initial distribution rate for the Class B Preferred Units from and including the date of original issue to, but not including, July 1, 2022 is 9.00% per year of the $25.00 liquidation preference per unit (equal to $2.25 per unit per year). On and after July 1, 2022, distributions on the Class B Preferred Units will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR plus a spread of 7.213%. The following table summarizes distributions declared on our Class B Preferred Units during the last two fiscal years: Date Declared Record Date Payment Date Amount Paid to Class B (in thousands) September 18, 2017 September 29, 2017 October 16, 2017 $ 5,670 December 19, 2017 December 29, 2017 January 15, 2018 $ 4,725 March 19, 2018 April 2, 2018 April 16, 2018 $ 4,725 June 19, 2018 July 2, 2018 July 16, 2018 $ 4,725 September 12, 2018 October 1, 2018 October 15, 2018 $ 4,725 December 17, 2018 December 31, 2018 January 15, 2019 $ 4,725 March 15, 2019 April 1, 2019 April 15, 2019 $ 4,725 The distribution amount paid on April 15, 2019 is included in accrued expenses and other payables in our consolidated balance sheet at March 31, 2019 . Class C Preferred Units On April 2, 2019, we issued 1,800,000 of our 9.625% Class C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (“Class C Preferred Units”) representing limited partner interests at a price of $25.00 per unit for net proceeds of $43.1 million (net of the underwriters’ discount of $1.4 million and estimated offering costs of $0.5 million ). At any time on or after April 15, 2024, we may redeem our Class C Preferred Units, in whole or in part, at a redemption price of $25.00 per Class C Preferred Unit plus an amount equal to all accumulated and unpaid distributions to, but not including, the date of redemption, whether or not declared. We may also redeem the Class C Preferred Units upon a change of control as defined in our partnership agreement. If we choose not to redeem the Class C Preferred Units, the Class C preferred unitholders may have the ability to convert the Class C Preferred Units to common units at the then applicable conversion rate. Class C preferred unitholders have no voting rights except with respect to certain matters set forth in our partnership agreement. Distributions on the Class C Preferred Units are payable on the 15th day of each January, April, July and October of each year to holders of record on the first day of each payment month. The initial distribution rate for the Class C Preferred Units from and including the date of original issue to, but not including, April 15, 2024, is 9.625% per year of the $25.00 liquidation preference per unit (equal to $2.41 per unit per year). On and after April 15, 2024, distributions on the Class C Preferred Units will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR plus a spread of 7.384%. Amended and Restated Partnership Agreement On April 2, 2019, NGL Energy Holdings LLC executed the Fifth Amended and Restated Agreement of Limited Partnership. The preferences, rights, powers and duties of holders of the Class C Preferred Units are defined in the amended and restated partnership agreement. The Class C Preferred Units rank senior to the common units, with respect to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up, and are on parity with the Class A Preferred Units (see above discussion regarding the redemption of these units) and Class B Preferred Units. The Class C Preferred Units have no stated maturity but we may redeem the Class C Preferred Units at any time on or after April 15, 2024 or upon the occurrence of a change in control. On June 13, 2017, NGL Energy Holdings LLC executed the Fourth Amended and Restated Agreement of Limited Partnership. The preferences, rights, powers and duties of holders of the Class B Preferred Units are defined in the amended and restated partnership agreement. The Class B Preferred Units rank senior to the common units, with respect to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up, and are on parity with the Class A Preferred Units (see above discussion regarding the redemption of these units). The Class B Preferred Units have no stated maturity but we may redeem the Class B Preferred Units at any time on or after July 1, 2022 or upon the occurrence of a change in control. On June 24, 2016, NGL Energy Holdings LLC executed the Third Amended and Restated Agreement of Limited Partnership. The preferences, rights, powers and duties of holders of the Class A Preferred Units are defined in the amended and restated partnership agreement. The Class A Preferred Units rank senior to the common units, with respect to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up. The Class A Preferred Units have no stated maturity and are not subject to mandatory redemption or any sinking fund and will remain outstanding indefinitely unless redeemed by the Partnership or converted into common units at the election of the Partnership or the Class A preferred unitholders or in connection with a change of control. See above for a discussion regarding the redemption of the Class A Preferred Units. Equity-Based Incentive Compensation Our general partner has adopted a long-term incentive plan (“LTIP”), which allows for the issuance of equity-based compensation. Our general partner has granted certain restricted units to employees and directors , which vest in tranches, subject to the continued service of the recipients. The awards may also vest upon a change of control, at the discretion of the board of directors of our general partner. No distributions accrue to or are paid on the restricted units during the vesting period. The restricted units include awards that vest contingent on the continued service of the recipients through the vesting date (the “Service Awards”). On April 1, 2017, we made an accounting policy election to account for actual forfeitures, rather than estimate forfeitures each period (as previously required). As a result, the cumulative effect adjustment, which represents the differential between the amount of compensation expense previously recorded and the amount that would have been recorded without assuming forfeitures, had no impact on our consolidated financial statements. The following table summarizes the Service Award activity during the years ended March 31, 2019 , 2018 and 2017 : Unvested Service Award units at March 31, 2016 2,297,132 Units granted 3,124,600 Units vested and issued (2,350,082 ) Units forfeited (363,150 ) Unvested Service Award units at March 31, 2017 2,708,500 Units granted 1,964,911 Units vested and issued (2,260,011 ) Units forfeited (134,525 ) Unvested Service Award units at March 31, 2018 2,278,875 Units granted 3,141,993 Units vested and issued (2,833,968 ) Units forfeited (278,500 ) Unvested Service Award units at March 31, 2019 2,308,400 In connection with the vesting of certain restricted units during the year ended March 31, 2019 , we canceled 26,993 of the newly-vested common units in satisfaction of $0.3 million of employee tax liability paid by us. Pursuant to the terms of the LTIP, these canceled units are available for future grants under the LTIP. The following table summarizes the scheduled vesting of our unvested Service Award units at March 31, 2019 : Year Ending March 31, Number of Units 2020 1,005,725 2021 869,425 2022 433,250 Total 2,308,400 Service Awards are valued at the average of the high/low sales price as of the grant date less the present value of the expected distribution stream over the vesting period using a risk-free interest rate. We record the expense for each Service Award on a straight-line basis over the requisite period for the entire award (that is, over the requisite service period of the last separately vesting portion of the award), ensuring that the amount of compensation cost recognized at any date at least equals the portion of the grant-date value of the award that is vested at that date. During the years ended March 31, 2019 , 2018 and 2017 , we recorded compensation expense related to Service Award units of $12.0 million , $16.2 million and $56.2 million , respectively. Of the restricted units granted and vested during the year ended March 31, 2019 , 1,745,801 units were granted as a bonus for performance during the year ended March 31, 2018. The total amount of these bonus payments was $20.4 million , of which we had accrued $6.3 million as of March 31, 2018. Also, 59,393 units were granted and vested as incentive compensation for the year ended March 31, 2018. The value of these awards was $0.7 million and was recorded within general and administrative expense in our consolidated statement of operations for the year ended March 31, 2018. Of the restricted units granted and vested during the year ended March 31, 2019 , 176,817 units were granted as a bonus for performance during the year ended March 31, 2019 . The total amount of these bonus payments was $2.4 million . Of the restricted units granted and vested during the year ended March 31, 2017, 1,008,091 units were granted as a bonus for performance during the year ended March 31, 2016. We accrued expense of $16.8 million during the year ended March 31, 2016 as an estimate of the value of such bonus units that would be granted. During the year ended March 31, 2017, we recorded an additional $2.2 million to true up the estimate to the $19.0 million of actual expense associated with these bonuses. Since the units were not granted until August 2016, the full $19.0 million is reflected in the expense during the year ended March 31, 2017. The following table summarizes the estimated future expense we expect to record on the unvested Service Award units at March 31, 2019 (in thousands): Year Ending March 31, 2020 $ 8,168 2021 4,154 2022 1,350 Total $ 13,672 Beginning in April 2015, our general partner granted units that vest contingent both on the continued service of the recipients through the vesting date and also on the performance of our common units relative to other entities in the Alerian MLP Index (the “Index”) over specified periods of time (the “Performance Awards”). These Performance Award units were granted to certain employees. Performance was to be calculated based on the return on our common units (including changes in the market price of the common units and distributions paid during the performance period) relative to the returns on the common units of the other entities in the Index. During the three months ended December 31, 2018, the compensation committee of the board of directors of our general partner terminated the Performance Award plan and all unvested outstanding Performance Awards units were canceled. Accordingly, as no replacement awards were granted, all previously unrecognized compensation cost was expensed as of the cancellation date. During the year ended March 31, 2019 , we recorded compensation expense related to the cancellation of the Performance units of $3.1 million which was recorded within general and administrative expense in our consolidated statement of operations for the year ended March 31, 2019 . The following table summarizes the Performance Award activity during the years ended March 31, 2019 , 2018 and 2017 : Unvested Performance Award units at March 31, 2016 637,382 Units granted 932,309 Units forfeited (380,691 ) Unvested Performance Award units at March 31, 2017 1,189,000 Units granted 224,000 Units forfeited (496,000 ) Unvested Performance Award units at March 31, 2018 917,000 Units forfeited (445,500 ) Units canceled (471,500 ) Unvested Performance Award units at March 31, 2019 — During the July 1, 2015 through June 30, 2018 performance period, the return on our common units was below the return of the 50th percentile of our peer companies in the Index. As a result, no Performance Award units vested on July 1, 2018 and performance units with the July 1, 2018 vesting date are considered to be forfeited. The fair value of the Performance Awards is estimated using a Monte Carlo simulation at the grant date. The significant inputs used to calculate the fair value of these awards include (i) the price per our common units at the grant date and the beginning of the performance period, (ii) a compounded risk-free interest rate, (iii) our compounded dividend yield, (iv) our historical volatility, (v) the volatility and correlations of our peers and (vi) the remaining performance period. We recorded the expense on a straight-line basis over the period beginning with the grant date and ending with the vesting date of the tranche. Any Performance Awards not earned at the end of the performance period will terminate, expire and otherwise be forfeited by the participants. During the years ended March 31, 2019 , 2018 and 2017, we recorded compensation expense related to Performance Award units of $4.9 million (including amounts recorded related to the cancellation of the Performance Award plan (see above)), $5.3 million and $7.2 million , respectively. The number of common units that may be delivered pursuant to awards under the LTIP is limited to 10% of our issued and outstanding common units. The maximum number of common units deliverable under the LTIP automatically increases to 10% of the issued and outstanding common units immediately after each issuance of common units, unless the plan administrator determines to increase the maximum number of units deliverable by a lesser amount. When an award is forfeited, canceled, exercised, paid or otherwise terminates or expires without the delivery of units, the units subject to such award are again available for new awards under the LTIP. The LTIP provides that units allocated to satisfy tax withholding obligations are not deemed to reduce availability for awards under the LTIP. Following a review of the LTIP, the compensation committee of the board of directors of our general partner determined that units vested after July 1, 2016 were inadvertently counted as a reduction to the Partnership’s LTIP reserve. Accordingly, after making the adjustments as provided for in the LTIP, as of March 31, 2019 , there are approximately 3.3 million units remaining available for issuance under the LTIP.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	12 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments Our cash and cash equivalents, accounts receivable, accounts payable, accrued expenses, and other current assets and liabilities (excluding derivative instruments) are carried at amounts which reasonably approximate their fair values due to their short-term nature. Commodity Derivatives The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported in our consolidated balance sheet at the dates indicated: March 31, 2019 March 31, 2018 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 3,754 $ (1,349 ) $ 2,835 $ (4,406 ) Level 2 measurements 8,882 (5,119 ) 7,013 (11,503 ) 12,636 (6,468 ) 9,848 (15,909 ) Netting of counterparty contracts (1) (1,577 ) 1,577 (664 ) 664 Net cash collateral provided (held) 1,740 (208 ) (4,718 ) 3,742 Commodity derivatives $ 12,799 $ (5,099 ) $ 4,466 $ (11,503 ) (1) Relates to commodity derivative assets and liabilities that are expected to be net settled on an exchange or through a netting arrangement with the counterparty. Our physical contracts that do not qualify as normal purchase normal sale transactions are not subject to such netting arrangements. The following table summarizes the accounts that include our commodity derivative assets and liabilities in our consolidated balance sheets at the dates indicated: March 31, 2019 2018 (in thousands) Prepaid expenses and other current assets $ 12,799 $ 4,466 Accrued expenses and other payables (4,960 ) (8,321 ) Other noncurrent liabilities (139 ) (3,182 ) Net commodity derivative asset (liability) $ 7,700 $ (7,037 ) The following table summarizes our open commodity derivative contract positions at the dates indicated. We do not account for these derivatives as hedges. Contracts Settlement Period Net Long Fair Value (in thousands) At March 31, 2019: Crude oil fixed-price (1) April 2019–December 2020 (1,961 ) 979 Propane fixed-price (1) April 2019–March 2020 198 608 Refined products fixed-price (1) April 2019–January 2021 (177 ) 376 Other April 2019–March 2022 4,205 6,168 Net cash collateral provided 1,532 Net commodity derivative asset $ 7,700 At March 31, 2018: Cross-commodity (2) April 2018–March 2019 155 $ (430 ) Crude oil fixed-price (1) April 2018–December 2019 (1,376 ) $ (8,960 ) Crude oil index (1) April 2018–April 2018 (10 ) $ (6 ) Propane fixed-price (1) April 2018–February 2019 14 1,849 Refined products fixed-price (1) April 2018–January 2020 (229 ) 215 Refined products index (1) April 2018–April 2018 (4 ) (17 ) Other April 2018–March 2022 1,288 (6,061 ) Net cash collateral held (976 ) Net commodity derivative liability $ (7,037 ) (1) We may have fixed price physical purchases, including inventory, offset by floating price physical sales or floating price physical purchases offset by fixed price physical sales. These contracts are derivatives we have entered into as an economic hedge against the risk of mismatches between fixed and floating price physical obligations. (2) We may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. These contracts are derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price. Amounts in the tables above do not include commodity derivative contract positions related to Mid-Con, Gas Blending and TPSL, as these amounts have been classified as current and noncurrent assets and liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the tables above do not include commodity derivative contract positions related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ). The following table summarizes the net gains (losses) recorded from our commodity derivatives to revenues and cost of sales in our consolidated statements of operations for the periods indicated (in thousands): Year Ended March 31, 2019 $ 10,817 2018 $ (41,263 ) 2017 $ (15,376 ) Amounts in the table above do not include net gains (losses) from our commodity derivatives related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ). Credit Risk We have credit policies that we believe minimize our overall credit risk, including an evaluation of potential counterparties’ financial condition (including credit ratings), collateral requirements under certain circumstances, and the use of industry standard master netting agreements, which allow for offsetting counterparty receivable and payable balances for certain transactions. At March 31, 2019 , our primary counterparties were retailers, resellers, energy marketers, producers, refiners, and dealers. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, as the counterparties may be similarly affected by changes in economic, regulatory or other conditions. If a counterparty does not perform on a contract, we may not realize amounts that have been recorded in our consolidated balance sheets and recognized in our net income. Interest Rate Risk The Revolving Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At March 31, 2019 , we had $1.2 billion of outstanding borrowings under the Revolving Credit Facility at a weighted average interest rate of 4.39% . Fair Value of Fixed-Rate Notes The following table provides fair values estimates of our fixed-rate notes at March 31, 2019 (in thousands): Senior Unsecured Notes: 2023 Notes $ 626,621 2025 Notes $ 375,126 For the Senior Unsecured Notes, the fair value estimates were developed based on publicly traded quotes and would be classified as Level 1 in the fair value hierarchy.

Segments

Segments	12 Months Ended
	Mar. 31, 2019
Segment Reporting [Abstract]
Segments	Segments The following table summarizes revenues related to our segments. Revenues for reporting periods beginning after April 1, 2018 are presented under Topic 606 (see Note 15 for a further discussion), while prior periods are not adjusted and continue to be reported under the accounting standard in effect for those periods. Transactions between segments are recorded based on prices negotiated between the segments. The “Corporate and Other” category in the table below includes certain corporate expenses that are not allocated to the reportable segments. Year Ended March 31, 2019 2018 (1) 2017 (1) (in thousands) Revenues: Crude Oil Logistics: Topic 606 revenues Crude oil sales $ 3,011,355 $ 2,151,203 $ 1,603,667 Crude oil transportation and other 148,738 122,786 70,027 Non-Topic 606 revenues 12,598 — — Elimination of intersegment sales (36,056 ) (13,914 ) (6,810 ) Total Crude Oil Logistics revenues 3,136,635 2,260,075 1,666,884 Water Solutions: Topic 606 revenues Disposal service fees 217,545 149,114 110,049 Sale of recovered hydrocarbons 72,678 58,948 31,103 Freshwater revenues 2,404 — — Other service revenues 9,017 21,077 18,449 Non-Topic 606 revenues 42 — — Total Water Solutions revenues 301,686 229,139 159,601 Liquids: Topic 606 revenues Propane sales 1,169,117 1,203,486 807,172 Butane sales 628,063 562,066 391,265 Other product sales 592,889 432,570 308,031 Service revenues 26,655 22,548 32,648 Non-Topic 606 revenues 21,608 — — Elimination of intersegment sales (23,291 ) (4,685 ) (1,944 ) Total Liquids revenues 2,415,041 2,215,985 1,537,172 Refined Products and Renewables: Topic 606 revenues Refined products sales 2,535,243 1,874,260 1,405,001 Renewables sales — 373,669 447,232 Service fees and other revenues — (87 ) — Non-Topic 606 revenues 299,190 — — Elimination of intersegment sales — (268 ) (469 ) Total Refined Products and Renewables revenues 2,834,433 2,247,574 1,851,764 Corporate and Other Non-Topic 606 revenues 1,362 1,174 844 Total Corporate and Other revenues 1,362 1,174 844 Total revenues $ 8,689,157 $ 6,953,947 $ 5,216,265 (1) We adopted ASC 606 as of April 1, 2018. Revenue reported in fiscal years 2018 and 2017 has not been changed from its previous presentation. The following table summarizes depreciation and amortization expense and operating income (loss) by segment for the periods indicated. Year Ended March 31, 2019 2018 2017 (in thousands) Depreciation and Amortization: Crude Oil Logistics $ 74,165 $ 80,387 $ 54,144 Water Solutions 108,162 98,623 101,758 Liquids 25,997 24,937 19,163 Refined Products and Renewables 631 672 936 Corporate and Other 3,018 3,779 3,612 Total depreciation and amortization (1) $ 211,973 $ 208,398 $ 179,613 Operating Income (Loss): Crude Oil Logistics $ (7,379 ) $ 122,904 $ (17,475 ) Water Solutions 210,525 (24,231 ) 44,587 Liquids (2,910 ) (93,113 ) 43,252 Refined Products and Renewables 12,198 261,249 243,090 Corporate and Other (85,706 ) (79,474 ) (86,985 ) Total operating income (loss) $ 126,728 $ 187,335 $ 226,469 (1) Amounts do not include amortization expense recorded within interest expense and cost of sales (see Note 7 and Note 8). The following table summarizes additions to property, plant and equipment and intangible assets by segment for the periods indicated. This information has been prepared on the accrual basis, and includes property, plant and equipment and intangible assets acquired in acquisitions. This information below does not include goodwill by segment. Year Ended March 31, 2019 2018 2017 (in thousands) Crude Oil Logistics $ 28,039 $ 36,762 $ 168,053 Water Solutions 567,637 102,261 109,008 Liquids 72,717 25,023 66,864 Corporate and Other 1,819 1,472 2,825 Total $ 670,212 $ 165,518 $ 346,750 The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment at the dates indicated: March 31, 2019 2018 (in thousands) Long-lived assets, net: Crude Oil Logistics $ 1,584,636 $ 1,638,558 Water Solutions 1,600,836 1,256,143 Liquids (1) 498,767 501,302 Refined Products and Renewables 29,477 30,384 Corporate and Other 26,569 31,516 Total $ 3,740,285 $ 3,457,903 (1) Includes $0.5 million and $0.6 million of non-US long-lived assets at March 31, 2019 and 2018 , respectively. March 31, 2019 2018 (in thousands) Total assets: Crude Oil Logistics $ 2,237,612 $ 2,285,813 Water Solutions 1,668,292 1,323,171 Liquids (1) 721,008 717,690 Refined Products and Renewables 383,026 341,495 Corporate and Other 77,019 102,211 Assets held for sale 815,536 1,380,742 Total $ 5,902,493 $ 6,151,122 (1) Includes $12.0 million and $27.5 million of non-US total assets at March 31, 2019 and 2018 , respectively. All of the tables above do not include amounts related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented and as held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 17 ).

Transactions with Affiliates

Transactions with Affiliates	12 Months Ended
	Mar. 31, 2019
Related Party Transactions [Abstract]
Transactions with Affiliates	Transactions with Affiliates A member of the board of directors of our general partner is an executive officer of WPX Energy, Inc. (“WPX”). We purchase crude oil from and sell crude oil to WPX (certain of the purchases and sales that were entered into in contemplation of each other are recorded on a net basis within revenues in our consolidated statement of operations). We also treat and dispose of wastewater and solids received from WPX. SemGroup Corporation (“SemGroup”) holds ownership interests in our general partner. We sell product to and purchase product from SemGroup, and these transactions are included within revenues and cost of sales, respectively, in our consolidated statements of operations . We also lease crude oil storage from SemGroup. We purchased ethanol from E Energy Adams, LLC, in which we previously held an ownership interest as an equity method investee. We sold our interest in E Energy Adams, LLC on May 3, 2018 (see Note 2 ). These transactions are reported within cost of sales in our consolidated statements of operations. The following table summarizes these related party transactions for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Sales to WPX $ 28,026 $ — $ — Purchases from WPX (1) $ 329,525 $ — $ — Sales to SemGroup $ 1,114 $ 606 $ 3,866 Purchases from SemGroup $ 4,395 $ 5,034 $ 12,254 Sales to entities affiliated with management $ 21,385 $ 268 $ 290 Purchases from entities affiliated with management $ 4,382 $ 3,870 $ 15,209 Sales to equity method investees $ — $ 294 $ 692 Purchases from equity method investees $ — $ 66,820 $ 121,336 (1) Amount primarily relates to purchases of crude oil under the definitive agreement we signed with WPX, as discussed further below. Accounts receivable from affiliates consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Receivables from NGL Energy Holdings LLC $ 7,277 $ 4,693 Receivables from WPX 5,185 — Receivables from SemGroup 71 49 Receivables from entities affiliated with management 334 24 Receivables from equity method investees — 6 Total $ 12,867 $ 4,772 Accounts payable to affiliates consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Payables to WPX $ 27,844 $ — Payables to entities affiliated with management 625 1,246 Payables to equity method investees — 8 Total $ 28,469 $ 1,254 Other Related Party Transactions Victory Propane On August 14, 2018, we sold our 50% interest in Victory Propane to Victory Propane, LLC. As consideration, we received a promissory note in the amount of $3.4 million , which encompassed the purchase price for our 50% interest plus the outstanding balance of the loan receivable of $2.6 million as of the date of the transaction. The promissory note bears no interest and matures on July 31, 2023. We discounted the promissory note to its net present value of $2.6 million , with the amount of the reduction in the value of the promissory note recorded as a loss within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. This was the final transaction in exiting the retail propane business and was considered to be inconsequential by management. As a result of the sale, Victory Propane is no longer considered a related party. At March 31, 2018, we had a loan receivable from Victory Propane, an equity method investee at the time (see Note 2 ), of $1.2 million . During the three months ended December 31, 2017 we completed a transaction with Victory Propane, an equity method investee at the time (See Note 2 ), to purchase Victory Propane’s Michigan assets. We paid Victory Propane $6.4 million in cash and received current assets, property, plant and equipment and customers. The allocation of the consideration was as follows (in thousands): Current assets $ 276 Property, plant and equipment 1,366 Intangible assets (customer relationships) 4,782 Fair value of net assets acquired $ 6,424 Victory Propane recognized a gain on this transaction. As all intra-entity profits and losses are eliminated between an investor and investee until realized, we eliminated our proportionate share of the gain from this transaction on our books. As a result, our underlying equity in the net assets of Victory Propane exceeded our investment (see Note 2 ), and this difference was amortized as income over the remaining life of the noncurrent assets acquired until they were sold on August 14, 2018. As the sale of virtually all of our remaining Retail Propane segment to Superior (see Note 1 ) included Victory Propane’s Michigan assets, we were able to recognize our proportionate share of the gain recognized by Victory Propane. As a result, we were able to reverse our proportionate share of their losses that had been recorded against the balance of the loan receivable and write up the value of our investment in Victory Propane to $0.8 million . Agreement with WPX During the three months ended June 30, 2018, we entered into a definitive agreement with WPX. Under this agreement, we agreed to provide WPX the benefit of our minimum shipping fees or deficiency credits (fees paid in previous periods that were in excess of the volumes actually shipped) totaling $67.7 million at the time of the transaction (as discussed further in Note 2 ), which can be utilized for volumes shipped that exceed the minimum monthly volume commitment in subsequent periods. As a result, we wrote-off these minimum shipping fees previously included within other noncurrent assets in our consolidated balance sheet (see Note 2 ) and recorded a loss within loss (gain) on disposal or impairment of assets, net . We also agreed that we would only ship crude oil that we are required to purchase from WPX in utilizing our allotted capacity on these pipelines and they agreed to be fully responsible to us for all deficiency payments (money due when our actual shipments are less than our allotted capacity) for the remaining term of our contract, which totaled $50.3 million at June 30, 2018 (as discussed further in Note 9 ). As consideration for this transaction, we paid WPX a net $35.3 million , which was recorded as a loss within loss (gain) on disposal or impairment of assets, net . Repurchase of Warrants On April 26, 2018 and June 23, 2017, we repurchased outstanding warrants, as discussed further in Note 10 , from funds managed by Oaktree, who were represented on the board of directors of our general partner (see Note 19). Grassland We previously had a loan receivable from Grassland Water Solutions, LLC (“Grassland”) and during the three months ended June 30, 2016, we received loan payments of $0.7 million from Grassland in accordance with the loan agreement. On June 3, 2016, we acquired the remaining 65% ownership interest in Grassland. Prior to the completion of this transaction, we accounted for our previously held 35% ownership interest in Grassland using the equity method of accounting. As we owned a controlling interest in Grassland, we revalued our previously held 35% ownership interest to fair value of $0.8 million and recorded a loss of $14.9 million . As the amount paid (cash plus the fair value of our previously held ownership interest) was less than the fair value of the assets acquired and liabilities assumed, we recorded a bargain purchase gain of $0.6 million . Once we acquired the remaining ownership interest in Grassland, the loan receivable was eliminated as Grassland was consolidated in our consolidated financial statements. As a result of the acquisition, we incurred an impairment charge of $1.7 million to write down the loan receivable to its fair value, which was reported within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. On November 29, 2016, we sold Grassland and received proceeds of $22.0 million and recorded a loss on disposal of $2.3 million during the three months ended December 31, 2016. This loss is reported within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations.

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
	Mar. 31, 2019
Defined Contribution Plan [Abstract]
Employee Benefit Plan	Employee Benefit Plan We have established a defined contribution 401(k) plan to assist our eligible employees in saving for retirement on a tax-deferred basis. The 401(k) plan permits all eligible employees to make voluntary pre-tax contributions to the plan, subject to applicable tax limitations. For every dollar that employees contribute up to 1% of their eligible compensation (as defined in the plan), we contribute one dollar, plus 50 cents for every dollar employees contribute between 1% and 6% of their eligible compensation (as defined in the plan). Our matching contributions prior to January 1, 2015 vest over five years and, effective January 1, 2015, our matching contributions vest over two years. Expenses under the plan for the years ended March 31, 2019 , 2018 and 2017 were $1.9 million , $1.7 million and $1.5 million , respectively. Expenses for matching contributions related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ).

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Mar. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	Revenue from Contracts with Customers Impact of Adoption We adopted ASC 606 on April 1, 2018, using the modified retrospective method. Revenues for reporting periods beginning after April 1, 2018 are presented under Topic 606, while prior periods are not adjusted and continue to be reported under the accounting standard in effect for those periods. We recorded an increase to the beginning balance of equity as of April 1, 2018, due to the cumulative impact of adopting the standard, as discussed further below. Based on our evaluation, we anticipate that from time to time, differences in the timing of revenues earned and our right to invoice customers may create contract assets or liabilities. These differences in timing would be the result of contracts that contain minimum volume commitments and tiered pricing provisions, primarily within our Water Solutions segment. In addition, we completed the process of implementing appropriate changes to our business processes, systems and controls to support recognition and disclosure under this standard. Furthermore, under this standard we made an accounting policy election to exclude from the measurement of the transaction price all taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction that we collect from a customer. As discussed previously, we sold our general partner interest in TransMontaigne Partners L.P. (“TLP”) and deferred a portion of the gain related to the sale of which the current portion was recorded in accrued expenses and other payables and the long-term portion was recorded in other noncurrent liabilities at March 31, 2018 within our consolidated balance sheet. During the years ended March 31, 2018 and 2017, we recognized $30.1 million and $30.1 million , respectively, of the deferred gain in our consolidated statements of operations. As this transaction was accounted for under the real estate guidance in ASC 360-20, Property, Plant and Equipment, we had been amortizing the gain over the life of the related lease agreements. Upon adoption of ASC 606, we determined that this transaction should be accounted for under the guidance of ASC 810-10-40 and utilizing the modified retrospective approach of adoption, the deferred gain as of March 31, 2018 of $139.3 million was recognized in the beginning balance of retained earnings as part of our cumulative effect adjustment at April 1, 2018. The following tables summarize the impact of adoption on our consolidated balance sheet at March 31, 2019 and our consolidated statements of operations for the year ended March 31, 2019 : Consolidated Balance Sheet March 31, 2019 As Reported Balances Without Adoption of ASC 606 Effect of Change (in thousands) Accrued expenses and other liabilities $ 107,759 $ 137,872 $ (30,113 ) Other noncurrent liabilities $ 63,542 $ 142,623 $ (79,081 ) Equity: General partner $ (50,603 ) $ (50,712 ) $ 109 Limited partners $ 2,067,197 $ 1,958,113 $ 109,084 Consolidated Statement of Operations March 31, 2019 As Reported Balances Without Adoption of ASC 606 Effect of Change (in thousands) Loss on disposal or impairment of assets, net $ 34,296 $ 4,183 $ 30,113 Operating income $ 126,728 $ 156,841 $ (30,113 ) Net income $ 339,395 $ 369,508 $ (30,113 ) Prior to April 1, 2018, we recognized revenue for services and products when all of the following criteria were met under Topic 605: (i) either services have been rendered or products have been delivered or sold; (ii) persuasive evidence of an arrangement existed; (iii) the price for services was fixed or determinable; and (iv) collectibility was reasonably assured. We recorded deferred revenue when we received amounts from our customers but had not yet met the criteria listed above. We recognized deferred revenue in our consolidated statement of operations when the criteria had been met and all services had been rendered. Effective April 1, 2018, we recognize revenue for services and products under revenue contracts as our obligations to either perform services or deliver or sell products under the contracts are satisfied. A performance obligation is a promise in a contract to transfer a distinct good or service to the customer. A contract’s transaction price is allocated to each distinct performance obligation in the contract and is recognized as revenue when, or as, the performance obligation is satisfied. Our revenue contracts in scope under ASC 606 primarily have a single performance obligation. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgment and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative stand-alone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can vary from those judgments and assumptions. We do not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration at March 31, 2018. Our costs to obtain or fulfill our revenue contracts were not material as of March 31, 2019 . The majority of our revenue agreements are within scope under ASC 606 and the remainder of our revenue comes from contracts that are accounted for as derivatives under ASC 815 or that contain nonmonetary exchanges or leases and are in scope under Topics 845 and 840, respectively. See Note 12 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Refined and Renewables segment includes $4.2 million of net gains related to changes in the mark-to-market value of these arrangements recorded during the year ended March 31, 2019 . Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 to 60 days. In instances where the timing of revenue recognition differs from the timing of invoicing, we have determined our contracts generally do not include a significant financing component. The primary purpose of our invoicing terms is to allow customers to secure the right to reserve the product or storage capacity to be received or used at a later date, not to receive financing from our customers or to provide customers with financing. We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. We include amounts billed to customers for shipping and handling costs in revenues in our consolidated statements of operations. Crude Oil Logistics Performance Obligations Within the Crude Oil Logistics segment, revenue is disaggregated into two primary revenue streams that include revenue from the sale of commodities and service revenue. For sales of commodities, we are obligated to deliver a predetermined amount of product on a month-to-month basis to our customers. For these types of agreements, revenue is recognized at a point in time based on when the product is delivered and control is transferred to the customer. For revenue received from services rendered, we are obligated to provide throughput services to move product via pipeline, truck, railcar, or marine vessel or to provide terminal maintenance services. In either case, the obligation is satisfied over time utilizing the output method based on each volume of product that is moved from the origination point to the final destination or based on the passage of time. Water Solutions Performance Obligations Within the Water Solutions segment, revenue is disaggregated into two primary revenue streams that include service revenue and commodity sales revenue. For contracts involving disposal services, we accept wastewater and solids for disposal at our facilities. In cases where we have agreed within a contract or are required by law to remove hydrocarbons from the wastewater, the skim oil will be valued as non-cash consideration. Ordinarily, it is required that the fair value of the skim oil is to be estimated at contract inception; however, due to variability of the form of the non-cash consideration, the amount and dollar value is unknown at the contract inception date. Accordingly, ASC 606-10-32-11 allows us to value the skim oil on the date in which the value becomes known. The Water Solutions segment has certain disposal contracts that contain the following types of terms or pricing structures that involve significant judgment that impacts the determination and timing of revenue. • Minimum volume commitments. We receive a shortfall fee if the customer does not deliver a certain amount of volume of wastewater over a specified period of time. At each reporting period, we make a determination as to the likelihood of earning this fee. We recognize revenue from these contracts when (i) actual volumes are received; and (ii) when the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote (also known as the breakage model). • Tiered pricing. For contracts with tiered pricing provisions, the period in which the tiers are earned and settled (i.e. the “reset period”) may vary from monthly to over a period of multiple months. If the tiered pricing is based on a month, we allocate the fee to the distinct daily service to which it relates. If the tiered pricing spans across multiple reporting periods, we estimate the total transaction price at the beginning of each reset period, based on the expected volumes. We revise our estimates of variable consideration at each reporting date throughout each reset period. • Volume discount pricing. Volume discount pricing is a form of variable consideration whereby the customer pays for the volumes delivered on a cumulative basis. Similar to tiered pricing, the period in which the cumulative volumes are earned and settled (i.e. the “reset period”) may vary from daily to over a period of multiple months. If the volume discount is based on a month, we allocate the fee to the distinct daily service to which it relates. If the volume discount period spans across multiple reporting periods, we estimate the total transaction price at the beginning of each reset period, based on the expected volumes. We revise the estimate of variable consideration at each reporting date. For all of our disposal contracts within the Water Solutions segment, revenue will be recognized over time utilizing the output method based on the volume of wastewater or solids we accept from the customer. For contracts that involve the sale of recovered hydrocarbons and freshwater, we will recognize revenue at a point in time, based on when control of the product is transferred to the customer. Liquids Performance Obligations Within the Liquids segment, revenue is disaggregated into two primary revenue streams that include revenue from the sale of commodities and providing services. For commodity sales, we are obligated to deliver a specified amount of product over a specified period of time. For these types of agreements, revenue is recognized at a point in time based on when the product is delivered and control is transferred to the customer. For revenue received from services rendered, we offer a variety of services which include: (i) storage services where product is commingled; (ii) railcar transportation services; (iii) transloading services; and (iv) logistics services. We are obligated to provide these services over a predetermined period of time. Revenue from service contracts is recognized at a point in time upon the transfer of control each month. All revenue from services is recognized over time utilizing the output method based on volumes stored or moved. Refined Products and Renewables Performance Obligations The Refined Products and Renewables segment has one distinct revenue stream, which is revenue from commodity sales. In these agreements, we are obligated to sell a predetermined amount of product over a specified period of time. Revenue for all commodity sales is recognized at a point in time once the customer has lifted the agreed-upon volumes. Remaining Performance Obligations Most of our service contracts are such that we have the right to consideration from a customer in an amount that corresponds directly with the value to the customer of our performance completed to date. Therefore, we are utilizing the practical expedient in ASC 606-10-55-18 under which we recognize revenue in the amount to which we have the right to invoice. Applying this practical expedient, we are not required to disclose the transaction price allocated to remaining performance obligations under these agreements. The following table summarizes the amount and timing of revenue recognition for such contracts at March 31, 2019 (in thousands): Fiscal Year Ending March 31, 2020 $ 167,061 2021 128,572 2022 119,016 2023 113,861 2024 99,430 Thereafter 242,032 Total $ 869,972 Many agreements are short-term in nature with a contract term of one year or less. For those contracts, we utilized the practical expedient in ASC 606-10-50 that exempts us from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. Additionally, for our product sales contracts, we have elected the practical expedient set out in ASC 606-10-50-14A, which states that we are not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these agreements, each unit of product represents a separate performance obligation and therefore future volumes are wholly unsatisfied and disclosure of transaction price allocated to remaining performance obligations is not required. Under product sales contracts, the variability arises as both volume and pricing (typically index-based) are not known until the product is delivered. Contract Assets and Liabilities Amounts owed from our customers under our revenue contracts are typically billed as the service is being provided on a monthly basis and are due within 1-30 days of billing, and are classified as accounts receivable-trade on our consolidated balance sheets. Under certain of our contracts, we recognize revenues in excess of billings, referred to as contract assets, within prepaid expenses and other current assets in our consolidated balance sheets. Accounts receivable from contracts with customers are presented within accounts receivable-trade and accounts receivable-affiliates in our consolidated balance sheets. Our contract asset balances primarily relate to our underground cavern storage contracts with multi-period contracts in which the fee escalates each year and the customer provides upfront payment at the beginning of the contract period. We did not record any contract assets during this period. Under certain of our contracts we may be entitled to receive payments in advance of satisfying our performance obligations under the contract. We recognize a liability for these payments in excess of revenue recognized, referred to as deferred revenue or contract liabilities, within advance payments received from customers in our consolidated balance sheets. Our deferred revenue primarily relates to: • Prepayments. Some revenue contracts contain prepayment provisions within our Liquids segment. Revenue received related to our underground cavern storage services is received upfront at the beginning of the contract period and is deferred until services have been rendered. In some cases, we also receive prepayments from customers purchasing commodities, which allows the customer to secure the right to receive their requested volumes in a future period. Revenue from these contracts is initially deferred, thus creating a contract liability. • Multi-period contract in which fee escalates each subsequent year of the contract. Revenue from these contracts is recognized over time based on a weighted average of what is expected to be received over the life of the contract. As the actual amount billed and received from the customer differs from the amount of revenue recognized, a contract liability is recorded. • Tiered pricing and volume discount pricing. As described above, we revise our estimates of variable consideration at each reporting date throughout each reset period. As the actual amount billed and received from the customer differs from the amount of revenue recognized, a contract liability is recorded. • Capital reimbursements. Certain contracts in our Water Solutions segment require that our customers reimburse us for capital expenditures related to the construction of long-lived assets, such as water gathering pipelines and custody transfer points, utilized to provide services to them under the revenue contracts. Because we consider these amounts as consideration from customers associated with ongoing services to be provided to customers, we defer these upfront payments in deferred revenue and recognize the amounts in revenue over the life of the associated revenue contract as the performance obligations are satisfied under the contract. The following tables summarizes the balances of our contract assets and liabilities at the dates indicated (in thousands): Balance at April 1, 2018 March 31, 2019 Accounts receivable from contracts with customers $ 542,593 $ 613,827 Contract liabilities balance at April 1, 2018 $ 7,889 Payment received and deferred 77,981 Payment recognized in revenue (77,409 ) Contract liabilities balance at March 31, 2019 $ 8,461 Amounts in the tables above do not include contract assets and liabilities related to TPSL, as these amounts have been classified as current assets and current liabilities held for sale within our March 31, 2019 consolidated balance sheet (see Note 1 and Note 17

Other Matters

Other Matters	12 Months Ended
	Mar. 31, 2019
Other Matters
Other Matters	Other Matters Sale of South Pecos Water Disposal Business On February 28, 2019, we completed the sale of our South Pecos water disposal business to a subsidiary of WaterBridge Resources LLC for $232.2 million in net cash proceeds and recorded a gain on disposal of $107.9 million during the year ended March 31, 2019 . This gain is reported within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. These operations include: (i) nine saltwater disposal facilities, (ii) all disposal agreements, commercial, surface and other contracts related to those facilities, (iii) pipelines connected to the facilities and (iv) several disposal permits. All of the assets sold in this transaction are located near the town of Pecos, Texas in southern Reeves and Ward counties. WaterBridge Resources LLC also has the option to acquire additional land and permits once the permitting process has been completed. As this sale transaction did not represent a strategic shift that will have a major effect on our operations or financial results, operations related to this portion of our Water Solutions segment have not been classified as discontinued operations. Sale of Bakken Saltwater Disposal Business On November 30, 2018, we completed the sale of NGL Water Solutions Bakken, LLC to an affiliate of Tallgrass Energy, LP for $85.0 million in net cash proceeds and recorded a gain on disposal of $33.4 million during the year ended March 31, 2019 within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. These operations include five saltwater disposal wells located in McKenzie and Dunn Counties, North Dakota. As this sale transaction did not represent a strategic shift that will have a major effect on our operations or financial results, operations related to this portion of our Water Solutions segment have not been classified as discontinued operations. Sawtooth Joint Venture On March 30, 2018, we completed the transaction to form a joint venture with Magnum Liquids, LLC, a portfolio company of Haddington Ventures LLC, along with Magnum Development, LLC and other Haddington-sponsored investment entities (collectively “Magnum”) t o focus on the storage of natural gas liquids and refined products by combining our Sawtooth salt dome storage facility with Magnum’s refined products rights and adjacent leasehold. Magnum acquired an approximately 28.5% interest in Sawtooth from us, in exchange for consideration consisting of a cash payment of approximately $37.6 million (excluding working capital) and the contribution of certain refined products rights and adjacent leasehold , which we valued at $21.6 million and recorded within intangible assets in our consolidated balance sheet. The disposition of this interest was accounted for as an equity transaction, no gain or loss was recorded and the carrying value of the noncontrolling interest was adjusted to reflect the change in ownership interest of the subsidiary. We own approximately 71.5% of the joint venture; and within the next two years, Magnum has options to acquire our remaining interest for an additional $182.4 million . Sale of Interest in Glass Mountain Pipeline, LLC (“Glass Mountain”) On December 22, 2017, we sold our previously held 50% interest in Glass Mountain for net proceeds of $292.1 million and recorded a gain on disposal of $108.6 million during the three months ended December 31, 2017 within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. As this sale transaction did not represent a strategic shift that will have a major effect on our operations or financial results, operations related to this portion of our Crude Oil Logistics segment have not been classified as discontinued operations. Termination of a Storage Sublease Agreement During the year ended March 31, 2017, we agreed to terminate a storage sublease agreement that was scheduled to commence in January 2017 and had a term of five years. For terminating this agreement, the counterparty agreed to pay us a specific amount in five equal payments which began in February 2017 and in January of the next four years and removed any future obligations of the Partnership. As a result, we discounted the future payments and recorded a gain of $16.2 million to other (expense) income, net in our consolidated statement of operations during the year ended March 31, 2017. Termination of Development Agreement On June 3, 2016, we entered into a purchase and sale agreement with the counterparty to the development agreement in our Water Solutions segment. Total cash consideration paid under the agreement was $49.6 million and in return we received the following: • Termination of the development agreement (see Note 7 ); • Additional interest in the water pipeline company we acquired in January 2016; • Release of contingent consideration liabilities attributed to certain of our water treatment and disposal facilities; • Certain parcels of land and permits to develop saltwater disposal wells and other parcels of land containing water wells and equipment; and • A two -year non-compete agreement with the counterparty. We accounted for the transaction as an acquisition of assets. We allocated $1.2 million of the total consideration to property, plant and equipment, $3.3 million to intangible assets, $2.8 million to noncontrolling interest, $25.5 million to the release of contingent consideration liabilities and $16.9 million to the termination of the development agreement. We recorded a $21.3 million gain on the release of $46.8 million of contingent consideration liabilities, which was recorded within (loss) gain on early extinguishment of liabilities, net in our consolidated statement of operations during the year ended March 31, 2017. For the termination of the development agreement, we recorded a loss of $22.7 million , which included the carrying value of the development agreement asset that was written off (see Note 7 ). This loss was recorded within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations during the year ended March 31, 2017. Sale of TLP Common Units On April 1, 2016, we sold all of the TLP common units we owned to ArcLight for approximately $112.4 million in cash and recorded a gain on disposal of $104.1 million during the year ended March 31, 2017. This gain is reported within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations.

Assets, Liabilities and Redeema

Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations	12 Months Ended
	Mar. 31, 2019
Discontinued Operations and Disposal Groups [Abstract]
Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations	Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations As discussed in Note 1 , we met the criteria for classifying certain assets and liabilities of the Mid-Con and Gas Blending businesses as held for sale and the operations as discontinued. On January 3, 2020, we completed the sale of Mid-Con to a third-party. See Note 1 for a further discussion. As discussed in Note 1 , we met the criteria for classifying the assets and liabilities of TPSL as held for sale and the operations as discontinued. On September 30, 2019, we completed the sale of TPSL and associated assets to Trajectory for total consideration of $233.8 million and recorded a loss on disposal of $181.2 million during the nine months ended December 31, 2019. See Note 1 and Note 19 for a further discussion. As discussed in Note 1 , as of June 30, 2018, we met the criteria for classifying the assets, liabilities and redeemable noncontrolling interest of our Retail Propane segment as held for sale and the operations as discontinued. On March 30, 2018, we sold a portion of our Retail Propane segment to DCC for net proceeds of $212.4 million in cash, and recorded a gain on disposal of $89.3 million during the year ended March 31, 2018. On July 10, 2018, we completed the sale of virtually all of our remaining Retail Propane segment to Superior for net proceeds of $889.8 million in cash, and recorded a gain on disposal of $408.9 million during the year ended March 31, 2019. On August 14, 2018, we sold our previously held interest in Victory Propane. See Note 1 for a further discussion. The following table summarizes the major classes of assets, liabilities and redeemable noncontrolling interest classified as held for sale at the dates indicated: March 31, 2019 2018 (in thousands) Current Assets Held for Sale Cash and cash equivalents $ — $ 4,113 Accounts receivable-trade, net 164,716 252,136 Inventories 327,015 402,904 Prepaid expenses and other current assets 89,254 49,518 Total current assets held for sale 580,985 708,671 Noncurrent Assets Held for Sale Property, plant and equipment, net 15,553 207,661 Goodwill 35,405 142,028 Intangible assets, net 137,446 279,395 Other noncurrent assets (1) 46,147 42,987 Total noncurrent assets held for sale 234,551 672,071 Total assets held for sale $ 815,536 $ 1,380,742 Current Liabilities Held for Sale Accounts payable-trade $ 85,602 $ 79,432 Accrued expenses and other payables 140,691 92,845 Advance payments received from customers 460 13,327 Current maturities of long-term debt — 2,550 Total current liabilities held for sale 226,753 188,154 Noncurrent Liabilities Held for Sale Long-term debt, net — 2,888 Other noncurrent liabilities 33 190 Total noncurrent liabilities held for sale 33 3,078 Total liabilities held for sale 226,786 191,232 Redeemable Noncontrolling Interest Held for Sale Redeemable noncontrolling interest — 9,927 Total liabilities and redeemable noncontrolling interest held for sale $ 226,786 $ 201,159 (1) Primarily comprised of tank bottoms, which are product volumes required for the operation of storage tanks, that are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. At March 31, 2019 and 2018, tank bottoms held in third party terminals consisted of 389,737 barrels and 366,212 barrels of refined products, respectively. Tank bottoms held in terminals we own are included within property, plant and equipment (see Note 5). The following table summarizes the results of operations from discontinued operations for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Revenues $ 15,398,608 $ 10,474,860 $ 7,904,143 Cost of sales 15,338,614 10,418,447 7,681,429 Operating expenses 37,348 137,780 134,879 General and administrative expense 2,716 11,471 15,727 Depreciation and amortization 9,593 44,314 43,592 Gain on disposal or impairment of assets, net (1) (407,608 ) (88,194 ) (196 ) Operating income (loss) from discontinued operations 417,945 (48,958 ) 28,712 Equity in earnings (loss) of unconsolidated entities 1,183 425 (746 ) Interest expense (126 ) (421 ) (877 ) Other income, net 837 1,930 1,244 Income (loss) from discontinued operations before taxes (2) 419,839 (47,024 ) 28,333 Income tax expense (989 ) (104 ) (6 ) Income (loss) from discontinued operations, net of tax $ 418,850 $ (47,128 ) $ 28,327 (1) Amount for the year ended March 31, 2019 includes a gain of $408.9 million on the sale of virtually all of our remaining Retail Propane segment to Superior on July 10, 2018, partially offset by a loss of $1.3 million on the sale of a portion of our Retail Propane segment to DCC on March 30, 2018 related to a working capital adjustment. (2) Amounts include income (loss) attributable to redeemable noncontrolling interests. Loss attributable to redeemable noncontrolling interest was $0.4 million for the year ended March 31, 2019 and income attributable to redeemable noncontrolling interest was $1.0 million for the year ended March 31, 2018 . Continuing Involvement As of March 31, 2019 , we have commitments to sell up to 7.4 million gallons of propane, valued at $5.7 million (based on the contract price) to Superior and DCC, the purchasers of our former Retail Propane segment, through March 2020. During the year ended March 31, 2019 , we received a combined $84.2 million from Superior and DCC for propane sold to them during the period.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Mar. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data (Unaudited)	Quarterly Financial Data (Unaudited) The following tables summarize our unaudited quarterly financial data. The computation of net income (loss) per common unit is done separately by quarter and year. The total of net income (loss) per common unit of the individual quarters may not equal net income (loss) per common unit for the year, due primarily to the income allocation between the general partner and limited partners and variations in the weighted average units outstanding used in computing such amounts. Our former Retail Propane segment’s business (included within discontinued operations, see Note 17 ) is seasonal due to weather conditions in our service areas. Its results are affected by winter heating season requirements, which generally results in net income during the period from October through March of each year and either net losses or lower net income during the period from April through September of each year. Our Liquids segment is also subject to seasonal fluctuations, as demand for propane and butane is typically higher during the winter months. Our operating revenues from our other segments are less weather sensitive. Additionally, the acquisitions described in Note 4 impact the comparability of the quarterly information within the year, and year to year. Quarter Ended Year Ended June 30, 2018 September 30, 2018 December 31, 2018 March 31, 2019 March 31, 2019 (in thousands, except unit and per unit amounts) Total revenues $ 2,054,952 $ 2,215,682 $ 2,295,369 $ 2,123,154 $ 8,689,157 Total cost of sales $ 1,946,565 $ 2,051,448 $ 2,048,659 $ 1,936,389 $ 7,983,061 (Loss) income from continuing operations $ (202,799 ) $ (31,725 ) $ 97,202 $ 57,867 $ (79,455 ) Net (loss) income $ (169,289 ) $ 354,939 $ 110,528 $ 43,217 $ 339,395 Net (loss) income attributable to NGL Energy Partners LP $ (168,546 ) $ 355,505 $ 110,835 $ 62,253 $ 360,047 Basic (loss) income per common unit (Loss) income from continuing operations $ (1.83 ) $ (0.45 ) $ 0.55 $ 0.31 $ (1.39 ) Net (loss) income $ (1.55 ) $ 2.70 $ 0.65 $ 0.20 $ 2.01 Diluted (loss) income per common unit (Loss) income from continuing operations $ (1.83 ) $ (0.45 ) $ 0.54 $ 0.31 $ (1.39 ) Net (loss) income $ (1.55 ) $ 2.70 $ 0.64 $ 0.19 $ 2.01 Basic weighted average common units outstanding 121,544,421 122,380,197 123,892,680 124,262,014 123,017,064 Diluted weighted average common units outstanding 121,544,421 122,380,197 125,959,751 126,926,589 123,017,064 Quarter Ended Year Ended June 30, 2017 September 30, 2017 December 31, 2017 March 31, 2018 March 31, 2018 (in thousands, except unit and per unit amounts) Total revenues $ 1,361,513 $ 1,452,072 $ 1,996,370 $ 2,143,992 $ 6,953,947 Total cost of sales $ 1,216,591 $ 1,279,871 $ 1,807,132 $ 1,959,967 $ 6,263,561 (Loss) income from continuing operations $ (13,004 ) $ (109,381 ) $ 105,035 $ (5,127 ) $ (22,477 ) Net (loss) income $ (63,707 ) $ (173,579 ) $ 56,769 $ 110,912 $ (69,605 ) Net (loss) income attributable to NGL Energy Partners LP $ (63,362 ) $ (173,371 ) $ 56,256 $ 109,602 $ (70,875 ) Basic (loss) income per common unit (Loss) income from continuing operations $ (0.19 ) $ (1.03 ) $ 0.73 $ (0.19 ) $ (0.68 ) Net (loss) income $ (0.61 ) $ (1.56 ) $ 0.33 $ 0.76 $ (1.08 ) Diluted (loss) income per common unit (Loss) income from continuing operations $ (0.19 ) $ (1.03 ) $ 0.71 $ (0.19 ) $ (0.68 ) Net (loss) income $ (0.61 ) $ (1.56 ) $ 0.32 $ 0.76 $ (1.08 ) Basic weighted average common units outstanding 120,535,909 121,314,636 120,844,008 121,271,959 120,991,340 Diluted weighted average common units outstanding 120,535,909 121,314,636 124,161,966 121,271,959 120,991,340 The following summarizes significant items recognized during the years ended March 31, 2019 and 2018 : Year Ended March 31, 2019 • During the fourth quarter of fiscal year 2019, we recorded a goodwill impairment charge related to Sawtooth (see Note 6 ); • On February 28, 2019, we sold our South Pecos water disposal business and recorded a gain (see Note 16 ); • On November 30, 2018, we sold our Bakken saltwater disposal business and recorded a gain (see Note 16 ); • On July 10, 2018, we sold virtually all of our remaining Retail Propane segment and recorded a gain (see Note 17 ); • On May 3, 2018, we sold our previously held interest in E Energy Adams, LLC and recorded a gain (see Note 2 ); and • During fiscal year 2019, we repurchased a portion of our 2019 Notes and 2023 Notes and redeemed the outstanding 2019 Notes and 2021 Notes and recorded a loss on the early extinguishment of these notes (see Note 8 ). Year Ended March 31, 2018 • On March 30, 2018, we sold a portion of our Retail Propane segment to DCC and recorded a gain (see Note 17 ); • On March 30, 2018, we closed the joint venture related to Sawtooth and sold a portion of our interest in Sawtooth (see Note 16 ); • On December 22, 2017, we sold our previously held interest in Glass Mountain (see Note 16 ); • During the second quarter of fiscal year 2018, we recorded a goodwill impairment charge related to Sawtooth (see Note 6 ); • During fiscal year 2018, we repurchased a portion of our 2019 Notes, 2023 Notes and 2025 Notes and recorded a net gain on the early extinguishment of these notes (see Note 8 ); and • During the first and third quarters of fiscal year 2018, we repurchased a portion of and then all of the remaining outstanding Senior Secured Notes and recorded a loss on the early extinguishment of these notes (see Note 8 ).

Subsequent Events

Subsequent Events	12 Months Ended
	Mar. 31, 2019
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Issuance of Class C Preferred Units On April 2, 2019, we issued the Class C Preferred Units. See Note 10 for a further discussion. Redemption of Class A Preferred Units On April 5, 2019, we made a partial redemption of the Class A Preferred Units and on May 11, 2019, we redeemed the remaining outstanding Class A Preferred Units. See Note 10 for a further discussion. In connection with the redemption, Jared Parker resigned from the board of directors of our general partner. Exercise of Warrants On April 5, 2019, Oaktree exercised all of its remaining warrants to purchase common units . See Note 10 for a further discussion. Issuance of 2026 Notes On April 9, 2019, we issued the 2026 Notes. See Note 8 for a further discussion. Acquisitions On May 14, 2019, we entered into a definitive agreement with Mesquite Disposals Unlimited, LLC (“Mesquite”) to acquire all of its assets for approximately $892.5 million . Mesquite SWD Inc. will remain the operator of the Mesquite assets led by Mesquite’s current management team. The assets consist of a fully interconnected produced water pipeline transportation and disposal system in Eddy and Lea Counties, New Mexico, and Loving County, Texas. At closing, the Mesquite system is expected to have 35 saltwater disposal wells in total. The transaction is subject to certain regulatory and other customary closing conditions and is expected to close in July 2019. On April 10, 2019, we acquired one saltwater disposal facility (including three saltwater disposal wells) for total consideration of approximately $53.0 million . On April 3, 2019, we acquired land and two saltwater disposal wells for total consideration of approximately $13.0 million . Dispositions On January 3, 2020, we completed the sale of our Mid-Con business. The business was sold to a third-party whom purchased the inventory and open derivative positions and assumed the Partnership’s obligations under certain system storage agreements. The Partnership retained all of the outstanding accounts receivable and accounts payable balances associated with this business that related to transactions prior to the closing date. To facilitate the assignment of the system storage agreements, the Partnership paid $6.3 million . See Note 1 and Note 17 for a further discussion of the transaction. On January 31, 2020, we paid Trajectory $41.7 million , which includes interest charges through the date of payment, related to the final working capital adjustment for the sale of TPSL. See Note 1 and Note 17 for a further discussion of the transaction.

Consolidating Guarantor and Non

Consolidating Guarantor and Non-Guarantor Financial Information	12 Months Ended
	Mar. 31, 2019
Consolidating Guarantor and Non-Guarantor Financial Information [Abstract]
Consolidating Guarantor and Non-Guarantor Financial Information	Consolidating Guarantor and Non-Guarantor Financial Information Certain of our wholly owned subsidiaries have, jointly and severally, fully and unconditionally guaranteed the Senior Unsecured Notes (see Note 8 ). Pursuant to Rule 3-10 of Regulation S-X, we have presented in columnar format the consolidating financial information for NGL Energy Partners LP (Parent), NGL Energy Finance Corp., the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis in the tables below. NGL Energy Partners LP and NGL Energy Finance Corp. are co-issuers of the Senior Unsecured Notes. Since NGL Energy Partners LP received the proceeds from the issuance of the Senior Unsecured Notes, all activity has been reflected in the NGL Energy Partners LP (Parent) column in the tables below. During the periods presented in the tables below, the status of certain subsidiaries changed, in that they either became guarantors of or ceased to be guarantors of the Senior Unsecured Notes. For purposes of the tables below, when the status of a subsidiary changes, all subsidiary activity is included in either the guarantor subsidiaries column or non-guarantor subsidiaries column based on the status of the subsidiary at the balance sheet date regardless of activity during the year. There are no significant restrictions that prevent the parent or any of the guarantor subsidiaries from obtaining funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries (other than the investments in non-guarantor subsidiaries) are restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act of 1933, as amended. For purposes of the tables below, (i) the consolidating financial information is presented on a legal entity basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to (from) consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the consolidating statement of cash flow tables below. As discussed further in Note 1 and Note 17 , certain assets and liabilities related to Mid-Con and Gas Blending and the assets and liabilities related to TPSL have been classified as held for sale within our March 31, 2019 and 2018 consolidated balance sheets. In addition, the assets and liabilities related to our former Retail Propane segment have been classified as held for sale within our March 31, 2018 consolidated balance sheet. The results of operations and cash flows related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment (including equity in earnings of Victory Propane) have been classified as discontinued operations for all periods presented and prior periods have been retrospectively adjusted in the consolidated statements of operations and consolidated statements of cash flows. Consolidating Balance Sheet (in Thousands) March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 12,798 $ — $ 3,728 $ 2,046 $ — $ 18,572 Accounts receivable-trade, net of allowance for doubtful accounts — — 996,192 2,011 — 998,203 Accounts receivable-affiliates — — 12,867 — — 12,867 Inventories — — 135,094 1,034 — 136,128 Prepaid expenses and other current assets — — 65,443 475 — 65,918 Assets held for sale — — 580,985 — — 580,985 Total current assets 12,798 — 1,794,309 5,566 — 1,812,673 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,620,084 208,856 — 1,828,940 GOODWILL — — 1,105,281 5,175 — 1,110,456 INTANGIBLE ASSETS, net of accumulated amortization — — 725,542 75,347 — 800,889 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 1,127 — — 1,127 NET INTERCOMPANY RECEIVABLES (PAYABLES) 862,186 — (808,610 ) (53,576 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 2,503,848 — 170,690 — (2,674,538 ) — OTHER NONCURRENT ASSETS — — 113,857 — — 113,857 ASSETS HELD FOR SALE — — 234,551 — — 234,551 Total assets $ 3,378,832 $ — $ 4,956,831 $ 241,368 $ (2,674,538 ) $ 5,902,493 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 872,122 $ 6,941 $ — $ 879,063 Accounts payable-affiliates 1 — 28,468 — — 28,469 Accrued expenses and other payables 25,497 — 80,765 1,497 — 107,759 Advance payments received from customers — — 7,550 911 — 8,461 Current maturities of long-term debt — — 648 — — 648 Liabilities held for sale — — 226,753 — — 226,753 Total current liabilities 25,498 — 1,216,306 9,349 — 1,251,153 LONG-TERM DEBT, net of debt issuance costs and current maturities 984,450 — 1,175,683 — — 2,160,133 OTHER NONCURRENT LIABILITIES — — 60,961 2,581 — 63,542 NONCURRENT LIABILITIES HELD FOR SALE — — 33 — — 33 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 149,814 — — — — 149,814 EQUITY: Partners’ equity 2,219,070 — 2,503,848 229,693 (2,733,286 ) 2,219,325 Accumulated other comprehensive loss — — — (255 ) — (255 ) Noncontrolling interests — — — — 58,748 58,748 Total equity 2,219,070 — 2,503,848 229,438 (2,674,538 ) 2,277,818 Total liabilities and equity $ 3,378,832 $ — $ 4,956,831 $ 241,368 $ (2,674,538 ) $ 5,902,493 Consolidating Balance Sheet (in Thousands) March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 16,915 $ — $ 3,329 $ 1,850 $ — $ 22,094 Accounts receivable-trade, net of allowance for doubtful accounts — — 815,404 5,148 — 820,552 Accounts receivable-affiliates — — 4,772 — — 4,772 Inventories — — 161,324 325 — 161,649 Prepaid expenses and other current assets — — 81,589 431 — 82,020 Assets held for sale — — 681,867 26,804 — 708,671 Total current assets 16,915 — 1,748,285 34,558 — 1,799,758 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,365,174 147,112 — 1,512,286 GOODWILL — — 1,093,270 77,260 — 1,170,530 INTANGIBLE ASSETS, net of accumulated amortization — — 691,382 83,705 — 775,087 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 17,236 — — 17,236 NET INTERCOMPANY RECEIVABLES (PAYABLES) 2,110,940 — (2,121,741 ) 10,801 — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,703,327 — 244,109 — (1,947,436 ) — LOAN RECEIVABLE-AFFILIATE — — 1,200 — — 1,200 OTHER NONCURRENT ASSETS — — 202,954 — — 202,954 ASSETS HELD FOR SALE — — 672,071 — — 672,071 Total assets $ 3,831,182 $ — $ 3,913,940 $ 353,436 $ (1,947,436 ) $ 6,151,122 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 778,965 $ 2,232 $ — $ 781,197 Accounts payable-affiliates 1 — 1,253 — — 1,254 Accrued expenses and other payables 41,104 — 94,853 1,285 — 137,242 Advance payments received from customers — — 4,022 3,867 — 7,889 Current maturities of long-term debt — — 646 — — 646 Liabilities held for sale — — 175,640 12,514 — 188,154 Total current liabilities 41,105 — 1,055,379 19,898 — 1,116,382 LONG-TERM DEBT, net of debt issuance costs and current maturities 1,704,909 — 974,831 — — 2,679,740 OTHER NONCURRENT LIABILITIES — — 167,398 5,926 — 173,324 NONCURRENT LIABILITIES HELD FOR SALE — — 3,078 — — 3,078 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 82,576 — — — — 82,576 REDEEMABLE NONCONTROLLING INTEREST HELD FOR SALE — — 9,927 — — 9,927 EQUITY: Partners’ equity 2,002,592 — 1,704,896 327,858 (2,030,939 ) 2,004,407 Accumulated other comprehensive loss — — (1,569 ) (246 ) — (1,815 ) Noncontrolling interests — — — — 83,503 83,503 Total equity 2,002,592 — 1,703,327 327,612 (1,947,436 ) 2,086,095 Total liabilities and equity $ 3,831,182 $ — $ 3,913,940 $ 353,436 $ (1,947,436 ) $ 6,151,122 Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 8,665,597 $ 27,542 $ (3,982 ) $ 8,689,157 COST OF SALES — — 7,986,019 1,024 (3,982 ) 7,983,061 OPERATING COSTS AND EXPENSES: Operating — — 217,597 13,468 — 231,065 General and administrative — — 106,595 812 — 107,407 Depreciation and amortization — — 201,513 10,460 — 211,973 (Gain) loss on disposal or impairment of assets, net — — (31,924 ) 66,220 — 34,296 Revaluation of liabilities — — (5,373 ) — — (5,373 ) Operating Income (Loss) — — 191,170 (64,442 ) — 126,728 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 2,533 — — 2,533 Interest expense (104,716 ) — (60,008 ) (46 ) 45 (164,725 ) Loss on early extinguishment of liabilities, net (12,340 ) — — — — (12,340 ) Other expense, net — — (30,187 ) — (231 ) (30,418 ) (Loss) Income From Continuing Operations Before Income Taxes (117,056 ) — 103,508 (64,488 ) (186 ) (78,222 ) INCOME TAX EXPENSE — — (1,233 ) — — (1,233 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 477,103 — (44,865 ) — (432,238 ) — Income (Loss) From Continuing Operations 360,047 — 57,410 (64,488 ) (432,424 ) (79,455 ) Income (Loss) From Discontinued Operations, Net of Tax — — 419,693 (1,029 ) 186 418,850 Net Income (Loss) 360,047 — 477,103 (65,517 ) (432,238 ) 339,395 LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS 20,206 20,206 LESS: NET LOSS ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS 446 446 NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ 360,047 $ — $ 477,103 $ (65,517 ) $ (411,586 ) $ 360,047 Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 6,935,485 $ 19,954 $ (1,492 ) $ 6,953,947 COST OF SALES — — 6,263,562 1,491 (1,492 ) 6,263,561 OPERATING COSTS AND EXPENSES: Operating — — 186,056 7,020 — 193,076 General and administrative — — 97,402 577 — 97,979 Depreciation and amortization — — 197,497 10,901 — 208,398 (Gain) loss on disposal or impairment of assets, net — — (133,993 ) 116,875 — (17,118 ) Revaluation of liabilities — — 20,124 592 — 20,716 Operating Income (Loss) — — 304,837 (117,502 ) — 187,335 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 7,539 — — 7,539 Interest expense (142,159 ) — (56,989 ) (46 ) 45 (199,149 ) Loss on early extinguishment of liabilities, net (23,201 ) — — — — (23,201 ) Other income, net — — 7,152 19 (819 ) 6,352 (Loss) Income From Continuing Operations Before Income Taxes (165,360 ) — 262,539 (117,529 ) (774 ) (21,124 ) INCOME TAX EXPENSE — — (1,353 ) — — (1,353 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 94,485 — (116,224 ) — 21,739 — (Loss) Income From Continuing Operations (70,875 ) — 144,962 (117,529 ) 20,965 (22,477 ) (Loss) Income From Discontinued Operations, Net of Tax — — (50,477 ) 2,575 774 (47,128 ) Net (Loss) Income (70,875 ) — 94,485 (114,954 ) 21,739 (69,605 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (240 ) (240 ) LESS: NET INCOME ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS (1,030 ) (1,030 ) NET (LOSS) INCOME ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ (70,875 ) $ — $ 94,485 $ (114,954 ) $ 20,469 $ (70,875 ) Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 5,197,416 $ 19,639 $ (790 ) $ 5,216,265 COST OF SALES — — 4,738,820 533 (790 ) 4,738,563 OPERATING COSTS AND EXPENSES: Operating — — 166,519 6,527 — 173,046 General and administrative — — 100,436 403 — 100,839 Depreciation and amortization — — 172,172 7,441 — 179,613 Gain on disposal or impairment of assets, net — — (208,982 ) — — (208,982 ) Revaluation of liabilities — — 6,305 412 — 6,717 Operating Income — — 222,146 4,323 — 226,469 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 3,830 — — 3,830 Revaluation of investments — — (14,365 ) — — (14,365 ) Interest expense (91,259 ) — (58,214 ) (174 ) 46 (149,601 ) Gain on early extinguishment of liabilities, net 8,507 — 16,220 — — 24,727 Other income, net — — 27,013 — (593 ) 26,420 (Loss) Income From Continuing Operations Before Income Taxes (82,752 ) — 196,630 4,149 (547 ) 117,480 INCOME TAX EXPENSE — — (1,933 ) — — (1,933 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 219,794 — (1,336 ) — (218,458 ) — Income From Continuing Operations 137,042 — 193,361 4,149 (219,005 ) 115,547 Income From Discontinued Operations, Net of Tax — — 26,433 1,347 547 28,327 Net Income 137,042 — 219,794 5,496 (218,458 ) 143,874 LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (6,832 ) (6,832 ) NET INCOME ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ 137,042 $ — $ 219,794 $ 5,496 $ (225,290 ) $ 137,042 Consolidating Statements of Comprehensive Income (Loss) (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income (loss) $ 360,047 $ — $ 477,103 $ (65,517 ) $ (432,238 ) $ 339,395 Other comprehensive (los s) income — — (18 ) 9 — (9 ) Comprehensive income (loss) $ 360,047 $ — $ 477,085 $ (65,508 ) $ (432,238 ) $ 339,386 Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (70,875 ) $ — $ 94,485 $ (114,954 ) $ 21,739 $ (69,605 ) Other comprehensive income (loss) — — 58 (45 ) — 13 Comprehensive (loss) income $ (70,875 ) $ — $ 94,543 $ (114,999 ) $ 21,739 $ (69,592 ) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income $ 137,042 $ — $ 219,794 $ 5,496 $ (218,458 ) $ 143,874 Other comprehensive loss — — (1,626 ) (45 ) — (1,671 ) Comprehensive income $ 137,042 $ — $ 218,168 $ 5,451 $ (218,458 ) $ 142,203 Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (116,033 ) $ — $ 295,293 $ (27,551 ) $ (186 ) $ 151,523 Net cash provided by operating activities-discontinued operations — — 182,506 3,221 — 185,727 Net cash (used in) provided by operating activities (116,033 ) — 477,799 (24,330 ) (186 ) 337,250 INVESTING ACTIVITIES: Capital expenditures — — (414,522 ) (41,064 ) — (455,586 ) Acquisitions, net of cash acquired — — (296,687 ) (3,927 ) — (300,614 ) Net settlements of commodity derivatives — — (10,173 ) — — (10,173 ) Proceeds from sales of assets — — 16,177 — — 16,177 Proceeds from divestitures of businesses and investments, net — — 335,809 — — 335,809 Investments in unconsolidated entities — — (389 ) — — (389 ) Distributions of capital from unconsolidated entities — — 1,440 — — 1,440 Repayments on loan for natural gas liquids facility — — 10,336 — — 10,336 Loan to affiliate — — (1,515 ) — — (1,515 ) Net cash used in investing activities-continuing operations — — (359,524 ) (44,991 ) — (404,515 ) Net cash provided by investing activities-discontinued operations — — 851,006 6,982 — 857,988 Net cash provided by (used in) investing activities — — 491,482 (38,009 ) — 453,473 FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 4,098,500 — — 4,098,500 Payments on revolving credit facilities — — (3,897,000 ) — — (3,897,000 ) Repayment and repurchase of senior secured and senior unsecured notes (737,058 ) — — — — (737,058 ) Payments on other long-term debt — — (653 ) — — (653 ) Debt issuance costs (30 ) — (1,353 ) — — (1,383 ) Contributions from noncontrolling interest owners, net — — — 169 — 169 Distributions to general and common unit partners and preferred unitholders (236,633 ) — — — — (236,633 ) Repurchase of warrants (14,988 ) — — — — (14,988 ) Common unit repurchases and cancellations (297 ) — — — — (297 ) Payments for settlement and early extinguishment of liabilities — — (4,577 ) — — (4,577 ) Net changes in advances with consolidated entities 1,100,922 — (1,163,504 ) 62,396 186 — Net cash provided by (used in) financing activities-continuing operations 111,916 — (968,587 ) 62,565 186 (793,920 ) Net cash used in financing activities-discontinued operations — — (295 ) (30 ) — (325 ) Net cash provided by (used in) financing activities 111,916 — (968,882 ) 62,535 186 (794,245 ) Net (decrease) increase in cash and cash equivalents (4,117 ) — 399 196 — (3,522 ) Cash and cash equivalents, beginning of period 16,915 — 3,329 1,850 — 22,094 Cash and cash equivalents, end of period $ 12,798 $ — $ 3,728 $ 2,046 $ — $ 18,572 Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (141,967 ) $ — $ 433,678 $ 9,411 $ (774 ) $ 300,348 Net cash (used in) provided by operating activities-discontinued operations — — (165,862 ) 3,481 — (162,381 ) Net cash (used in) provided by operating activities (141,967 ) — 267,816 12,892 (774 ) 137,967 INVESTING ACTIVITIES: Capital expenditures — — (130,760 ) (3,001 ) — (133,761 ) Acquisitions, net of cash acquired — — 3,100 (22,997 ) — (19,897 ) Net settlements of commodity derivatives — — (39,113 ) — — (39,113 ) Proceeds from sales of assets — — 33,844 — — 33,844 Proceeds from divestitures of businesses and investments, net — — 292,112 37,668 — 329,780 Transaction with Victory Propane (Note 13) — — (6,424 ) — — (6,424 ) Investments in unconsolidated entities — — (21,465 ) — — (21,465 ) Distributions of capital from unconsolidated entities — — 11,969 — — 11,969 Repayments on loan for natural gas liquids facility — — 10,052 — — 10,052 Loan to affiliate — — (2,510 ) — — (2,510 ) Repayments on loan to affiliate — — 4,160 — — 4,160 Net cash provided by investing activities-continuing operations — — 154,965 11,670 — 166,635 Net cash provided by (used in) investing activities-discontinued operations — — 104,666 (719 ) — 103,947 Net cash provided by investing activities — — 259,631 10,951 — 270,582 FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 2,434,500 — — 2,434,500 Payments on revolving credit facilities — — (2,279,500 ) — — (2,279,500 ) Repayment and repurchase of senior secured and senior unsecured notes (486,699 ) — — — — (486,699 ) Payments on other long-term debt — — (877 ) — — (877 ) Debt issuance costs (692 ) — (2,008 ) — — (2,700 ) Contributions from noncontrolling interest owners, net — — — 23 — 23 Distributions to general and common unit partners and preferred unitholders (225,067 ) — — — — (225,067 ) Distributions to noncontrolling interest owners — — — (3,082 ) — (3,082 ) Proceeds from sale of preferred units, net of offering costs 202,731 — — — — 202,731 Repurchase of warrants (10,549 ) — — — — (10,549 ) Common unit repurchases and cancellations (15,817 ) — — — — (15,817 ) Payments for settlement and early extinguishment of liabilities — — (3,408 ) — — (3,408 ) Net changes in advances with consolidated entities 688,718 — (669,452 ) (20,040 ) 774 — Net cash provided by (used in) financing activities-continuing operations 152,625 — (520,745 ) (23,099 ) 774 (390,445 ) Net cash used in financing activities-discontinued operations — — (3,446 ) (390 ) — (3,836 ) Net cash provided by (used in) financing activities 152,625 — (524,191 ) (23,489 ) 774 (394,281 ) Net increase in cash and cash equivalents 10,658 — 3,256 354 — 14,268 Cash and cash equivalents, beginning of period 6,257 — 73 1,496 — 7,826 Cash and cash equivalents, end of period $ 16,915 $ — $ 3,329 $ 1,850 $ — $ 22,094 Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (749,250 ) $ — $ 750,978 $ 16,675 $ (547 ) $ 17,856 Net cash (used in) provided by operating activities-discontinued operations — — (47,923 ) 5,029 — (42,894 ) Net cash (used in) provided by operating activities (749,250 ) — 703,055 21,704 (547 ) (25,038 ) INVESTING ACTIVITIES: Capital expenditures — — (296,395 ) (6,367 ) — (302,762 ) Acquisitions, net of cash acquired — — (41,928 ) — — (41,928 ) Net settlements of commodity derivatives — — 9,648 — — 9,648 Proceeds from sales of assets — — 28,232 — — 28,232 Proceeds from divestitures of businesses and investments, net — — 112,370 22,000 — 134,370 Investments in unconsolidated entities — — (2,105 ) — — (2,105 ) Distributions of capital from unconsolidated entities — — 9,692 — — 9,692 Repayments on loan for natural gas liquids facility — — 8,916 — — 8,916 Loan to affiliate — — (3,200 ) — — (3,200 ) Repayments on loan to affiliate — — 655 — — 655 Payment to terminate development agreement — — (16,875 ) — — (16,875 ) Net cash (used in) provided by investing activities-continuing operations — — (190,990 ) 15,633 — (175,357 ) Net cash used in investing activities-discontinued operations — — (175,371 ) (12,398 ) — (187,769 ) Net cash (used in) provided by investing activities — — (366,361 ) 3,235 — (363,126 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 1,700,000 — — 1,700,000 Payments on revolving credit facilities — — (2,733,500 ) — — (2,733,500 ) Issuance of senior unsecured notes 1,200,000 — — — — 1,200,000 Repayment and repurchase of senior secured and senior unsecured notes (21,193 ) — — — — (21,193 ) Payments on other long-term debt — — (46,153 ) — — (46,153 ) Debt issuance costs (21,868 ) — (11,690 ) — — (33,558 ) Contributions from general partner 49 — — — — 49 Contributions from noncontrolling interest owners, net — — — 672 — 672 Distributions to general and common unit partners and preferred unitholders (181,581 ) — — — — (181,581 ) Distributions to noncontrolling interest owners — — — (3,292 ) — (3,292 ) Proceeds from sale of preferred units, net of offering costs 234,975 — — — — 234,975 Proceeds from sale of common units, net of offering costs 287,136 — — — — 287,136 Payments for settlement and early extinguishment of liabilities — — (28,468 ) — — (28,468 ) Net changes in advances with consolidated entities (767,760 ) — 788,334 (21,121 ) 547 — Net cash provided by (used in) financing activities-continuing operations 729,758 — (331,477 ) (23,741 ) 547 375,087 Net cash used in financing activities-discontinued operations — — (3,443 ) (190 ) — (3,633 ) Net cash provided by (used in) financing activities 729,758 — (334,920 ) (23,931 ) 547 371,454 Net (decrease) increase in cash and cash equivalents (19,492 ) — 1,774 1,008 — (16,710 ) Cash and cash equivalents, beginning of period 25,749 — (1,701 ) 488 — 24,536 Cash and cash equivalents, end of period $ 6,257 $ — $ 73 $ 1,496 $ — $ 7,826

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). The accompanying consolidated financial statements include our accounts and those of our controlled subsidiaries. Intercompany transactions and account balances have been eliminated in consolidation. Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. We also own an undivided interest in a crude oil pipeline, and include our proportionate share of assets, liabilities, and expenses related to this pipeline in our consolidated financial statements.
Use of Estimates	Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amount of assets and liabilities reported at the date of the consolidated financial statements and the amount of revenues and expenses reported during the periods presented. Critical estimates we make in the preparation of our consolidated financial statements include, among others, determining the fair value of assets and liabilities acquired in acquisitions, the fair value of derivative instruments, the collectibility of accounts receivable, the recoverability of inventories, useful lives and recoverability of property, plant and equipment and amortizable intangible assets, the impairment of long-lived assets and goodwill, the fair value of asset retirement obligations, the value of equity-based compensation, accruals for environmental matters and estimating certain revenues. Although we believe these estimates are reasonable, actual results could differ from those estimates.
Fair Value Measurements	Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. Fair value is based upon assumptions that market participants would use when pricing an asset or liability. We use the following fair value hierarchy, which prioritizes valuation technique inputs used to measure fair value into three broad levels: • Level 1: Quoted prices in active markets for identical assets and liabilities that we have the ability to access at the measurement date. • Level 2: Inputs (other than quoted prices included within Level 1) that are either directly or indirectly observable for the asset or liability, including (i) quoted prices for similar assets or liabilities in active markets, (ii) quoted prices for identical or similar assets or liabilities in inactive markets, (iii) inputs other than quoted prices that are observable for the asset or liability, and (iv) inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and forward commodity contracts. We determine the fair value of all of our derivative financial instruments utilizing pricing models for similar instruments. Inputs to the pricing models include publicly available prices and forward curves generated from a compilation of data gathered from third parties. • Level 3: Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall into different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to a fair value measurement requires judgment, considering factors specific to the asset or liability.
Derivative Financial Instruments	Derivative Financial Instruments We record all derivative financial instrument contracts at fair value in our consolidated balance sheets except for certain physical contracts that qualify for the normal purchase and normal sale election . Under this accounting policy election, we do not record the physical contracts at fair value at each balance sheet date; instead, we record the purchase or sale at the contracted value once the delivery occurs. We have not designated any financial instruments as hedges for accounting purposes. All changes in the fair value of our physical contracts that do not qualify as normal purchases and normal sales and settlements (whether cash transactions or non-cash mark-to-market adjustments) are reported either within revenue (for sales contracts) or cost of sales (for purchase contracts) in our consolidated statements of operations, regardless of whether the contract is physically or financially settled. We utilize various commodity derivative financial instrument contracts to attempt to reduce our exposure to price fluctuations. We do not enter into such contracts for trading purposes. Changes in assets and liabilities from commodity derivative financial instruments result primarily from changes in market prices, newly originated transactions, and the timing of settlements and are reported within cost of sales on the consolidated statements of operations, along with related settlements. We attempt to balance our contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. However, net unbalanced positions can exist or are established based on our assessment of anticipated market movements. Inherent in the resulting contractual portfolio are certain business risks, including commodity price risk and credit risk. Commodity price risk is the risk that the market value of crude oil, natural gas liquids, or refined and renewables products will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. Procedures and limits for managing commodity price risks and credit risks are specified in our market risk policy and credit policy, respectively. Open commodity positions and market price changes are monitored daily and are reported to senior management and to marketing operations personnel. Credit risk is monitored daily and exposure is minimized through customer deposits, restrictions on product liftings, letters of credit, and entering into master netting agreements that allow for offsetting counterparty receivable and payable balances for certain transactions.
Cost of Sales	Cost of Sales We include all costs we incur to acquire products, including the costs of purchasing, terminaling, and transporting inventory, prior to delivery to our customers, in cost of sales. Cost of sales excludes depreciation of our property, plant and equipment.
Depreciation and Amortization	Depreciation and Amortization Depreciation and amortization in our consolidated statements of operations includes all depreciation of our property, plant and equipment and amortization of intangible assets other than debt issuance costs, for which the amortization is recorded to interest expense, and certain contract-based intangible assets, for which the amortization is recorded to cost of sales.
Income Taxes	Income Taxes We qualify as a partnership for income tax purposes. As such, we generally do not pay United States federal income tax. Rather, each owner reports his or her share of our income or loss on his or her individual tax return. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined, as we do not have access to information regarding each partner’s basis in the Partnership. We have certain taxable corporate subsidiaries in the United States and Canada, and our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales. Our fiscal years 2015 to 2018 generally remain subject to examination by federal, state, and Canadian tax authorities. We utilize the asset and liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply in the years in which these temporary differences are expected to be recovered or settled. Changes in tax rates are recognized in income in the period that includes the enactment date. A publicly traded partnership is required to generate at least 90% of its gross income (as defined for federal income tax purposes) from certain qualifying sources. Income generated by our taxable corporate subsidiaries is excluded from this qualifying income calculation. Although we routinely generate income outside of our corporate subsidiaries that is non-qualifying, we believe that at least 90% of our gross income has been qualifying income for each of the calendar years since our IPO. During the year ended March 31, 2019 , we recognized a deferred tax liability of $16.3 million as a result of acquiring a corporation in connection with one of our acquisitions (see Note 4 ). The deferred tax liability is the tax effected cumulative temporary difference between the GAAP basis and tax basis of the acquired assets within the corporation. For GAAP purposes, certain of the acquired assets will be depreciated and amortized over time which will lower the GAAP basis. The deferred tax benefit recorded for the year ended March 31, 2019 is $1.5 million with an effective tax rate of 31% . The deferred tax liability is $14.8 million at March 31, 2019 and is included within other noncurrent liabilities in our consolidated balance sheet. We evaluate uncertain tax positions for recognition and measurement in the consolidated financial statements. To recognize a tax position, we determine whether it is more likely than not that the tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position. A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the consolidated financial statements. We had no material uncertain tax positions that required recognition in our consolidated financial statements at March 31, 2019 or 2018 .
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand and time deposits, and funds invested in highly liquid instruments with maturities of three months or less at the date of purchase. At times, certain account balances may exceed federally insured limits.
Accounts Receivable and Concentration of Credit Risk	Accounts Receivable and Concentration of Credit Risk We operate in the United States and Canada. We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions. The allowance for doubtful accounts is based on our assessment of the collectibility of customer accounts, which assessment considers the overall creditworthiness of customers and any specific disputes. Accounts receivable are considered past due or delinquent based on contractual terms. We write off accounts receivable against the allowance for doubtful accounts when collection efforts have been exhausted. We execute netting agreements with certain customers to mitigate our credit risk. Receivables and payables are reflected at a net balance to the extent a netting agreement is in place and we intend to settle on a net basis.
Inventories	Inventories Our inventories are valued at the lower of cost or net realizable value, with cost determined using either the weighted-average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage, and with net realizable value defined as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. In performing this analysis, we consider fixed-price forward commitments.
Investments in Unconsolidated Entities	Investments in Unconsolidated Entities Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. Investments in partnerships and limited liability companies, unless our investment is considered to be minor, and investments in unincorporated joint ventures are also accounted for using the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheets; instead, our ownership interests are reported within investments in unconsolidated entities on our consolidated balance sheets. Under the equity method, the investment is recorded at acquisition cost, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses, distributions paid, and amortization of any excess investment. Excess investment is the amount by which our total investment exceeds our proportionate share of the net assets of the investee. We consider distributions received from unconsolidated entities which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and are classified as operating activities in our consolidated statements of cash flows. We consider distributions received from unconsolidated entities in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in our consolidated statements of cash flows.
Variable Interest Entity	Variable Interest Entity Victory Propane was formed as a joint venture in April 2015 by us and an unrelated third party. The business purpose of Victory Propane is to acquire and/or develop retail propane operations in a defined geographic area. In conjunction with the formation of Victory Propane, we agreed to provide Victory Propane a revolving line of credit of $5.0 million
Property, Plant and Equipment	Property, Plant and Equipment We record property, plant and equipment at cost, less accumulated depreciation. Acquisitions and improvements are capitalized, and maintenance and repairs are expensed as incurred. As we dispose of assets, we remove the cost and related accumulated depreciation from the accounts, and any resulting gain or loss is included within loss (gain) on disposal or impairment of assets, net . We compute depreciation expense of our property, plant and equipment using the straight-line method over the estimated useful lives of the assets (see Note 5 ).
Intangible Assets	Intangible Assets Our intangible assets include contracts and arrangements acquired in business combinations, including customer relationships, customer commitments, pipeline capacity rights, rights-of-way and easements, water rights, executory contracts and other agreements, covenants not to compete, and trade names. In addition, we capitalize certain debt issuance costs associated with the revolving credit facilities. We amortize the majority of our intangible assets on a straight-line basis over the estimated useful lives of the assets (see Note 7 ). We amortize debt issuance costs over the terms of the related debt using a method that approximates the effective interest method.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets We evaluate the carrying value of our long-lived assets (property, plant and equipment and amortizable intangible assets) for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is less than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group. When we cease to use an acquired trade name, we test the trade name for impairment using the relief from royalty method and we begin amortizing the trade name over its estimated useful life as a defensive asset. See Note 5 and Note 7 for a further discussion of long-lived asset impairments recognized in the consolidated statements of operations. We evaluate our equity method investments for impairment when we believe the current fair value may be less than the carrying amount and record an impairment if we believe the decline in value is other than temporary.
Goodwill	Goodwill Goodwill represents the excess of the consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities assumed. Business combinations are accounted for using the “acquisition method” (see Note 4 ). We expect that all of our goodwill at March 31, 2019 is deductible for federal income tax purposes. Goodwill and indefinite-lived intangible assets are not amortized, but instead are evaluated for impairment at least annually. We perform our annual assessment of impairment during the fourth quarter of our fiscal year, and more frequently if circumstances warrant. To perform this assessment, we first consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. If we conclude that it is more likely than not that the fair value of a reporting unit does not exceed its carrying amount, we calculate the fair value for the reporting unit and compare the amount to its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its fair value, goodwill is considered to be impaired and the goodwill balance is reduced by the difference between the fair value and carrying amount of the reporting unit. Estimates and assumptions used to perform the impairment evaluation are inherently uncertain and can significantly affect the outcome of the analysis. The estimates and assumptions we used in the annual goodwill impairment assessment included market participant considerations and future forecasted operating results. Changes in operating results and other assumptions could materially affect these estimates. See Note 6 for a further discussion and analysis of our goodwill impairment assessment.
Product Exchanges	Product Exchanges Quantities of products receivable or returnable under exchange agreements are reported within prepaid expenses and other current assets and within accrued expenses and other payables in our consolidated balance sheets. We estimate the value of product exchange assets and liabilities based on the weighted-average cost basis of the inventory we have delivered or will deliver on the exchange, plus or minus location differentials. Product exchanges related to TPSL have been classified as current assets and current liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, product exchanges related to our former Retail Propane segment have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Noncontrolling Interests	Noncontrolling Interests Noncontrolling interests represent the portion of certain consolidated subsidiaries that are owned by third parties. Amounts are adjusted by the noncontrolling interest holder’s proportionate share of the subsidiaries’ earnings or losses each period and any distributions that are paid. Noncontrolling interests are reported as a component of equity, unless the noncontrolling interest is considered redeemable, in which case the noncontrolling interest is recorded between liabilities and equity (mezzanine or temporary equity) in our consolidated balance sheet. The redeemable noncontrolling interest is adjusted at each balance sheet date to its maximum redemption value if the amount is greater than the carrying value. The redeemable noncontrolling interest is classified as held for sale in our March 31, 2018 consolidated balance sheet (see Note 17
Acquisitions	Acquisitions To determine if a transaction should be accounted for as a business combination or an acquisition of assets, we first calculate the relative fair values of the assets acquired. If substantially all of the relative fair value is concentrated in a single asset or group of similar assets, or if not but the transaction does not include a significant process (does not meet the definition of a business), we record the transaction as an acquisition of assets. For acquisitions of assets, the purchase price is allocated based on the relative fair values. For an acquisition of assets, goodwill is not recorded. All other transactions are recorded as business combinations. We record the assets acquired and liabilities assumed in a business combination at their acquisition date fair values. For a business combination, the excess of the purchase price over the net fair value of acquired assets and assumed liabilities is recorded as goodwill, which is not amortized but instead is evaluated for impairment at least annually (as described above). Pursuant to GAAP, an entity is allowed a reasonable period of time (not to exceed one year) to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. As discussed in Note 4 , certain of our acquisitions are still within this measurement period, and as a result, the acquisition date fair values we have recorded for the assets acquired and liabilities assumed are subject to change.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-13, “Financial Instruments-Credit Losses.” The ASU requires a financial asset (or a group of financial assets) measured at amortized cost to be presented at the net amount expected to be collected, which would include accounts receivable. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectibility of the reported amount. The ASU is effective for the Partnership beginning April 1, 2020, and requires a modified retrospective method of adoption, although early adoption is permitted. We are currently in the process of assessing the impact of this ASU on our consolidated financial statements. In February 2016, the FASB issued ASC 842, “Leases.” This will replace previous lease accounting guidance in GAAP. The new guidance requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. It also retains a distinction between finance leases and operating leases. This guidance is effective for the Partnership beginning April 1, 2019. We evaluated our current leases and other contracts that may be considered leases under the new standard and the impact on our internal controls, accounting policies and financial statements and disclosures. Our evaluation process includes compiling a database of our leases, implementing accounting software to assist with compliance and developing internal controls to ensure completeness and accuracy of our leases meeting the scope of ASC 842. Based on our current population of leases, we expect the impact of ASC 842 to increase our assets and liabilities by between $533 million and $563 million due to the recognition of right-of-use assets and lease liabilities. We elected the following transitional practical expedients, which will allow us to not evaluate land easements prior to April 1, 2019: use hindsight in determining the lease term; to not reassess whether current or expired contracts contain leases; to not reassess the lease classification for any expired or existing leases; and to not reassess initial costs. We also expect to elect the optional transition method to record the adoption impact through a cumulative effect adjustment to equity. On April 1, 2018, we adopted ASC 606, “Revenue from Contracts with Customers,” using a modified retrospective approach of adoption. ASC 606 supersedes previous revenue recognition requirements in Topic 605, “Revenue Recognition,” and includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. To achieve this core principle, more judgment and estimates are required within the revenue recognition process than required under Topic 605. In addition, ASC 606 requires significantly expanded disclosures related to the nature, timing, amount and uncertainty of revenue and cash flows arising from contracts with customers. See Note 15 for a further discussion of the impact of adoption of ASC 606 on our consolidated financial statements and our revenue recognition policies. On April 1, 2018, we adopted ASU No. 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities.” One of the provisions of ASU No. 2016-01 was to supersede the guidance to classify equity securities with readily determinable fair value into different categories (that is, trading or available-for-sale) and require equity securities to be measured at fair value with changes in fair value recognized through net income. As a result of the adoption, we recorded a cumulative effect adjustment of $1.6 million , moving the unrealized loss from accumulated other comprehensive income to limited partners’ equity.

Equity (Policies)

Equity (Policies)	12 Months Ended
	Mar. 31, 2019
Equity [Abstract]
Forfeitures	On April 1, 2017, we made an accounting policy election to account for actual forfeitures, rather than estimate forfeitures each period (as previously required). As a result, the cumulative effect adjustment, which represents the differential between the amount of compensation expense previously recorded and the amount that would have been recorded without assuming forfeitures, had no impact on our consolidated financial statements.
Service Awards	Service Awards are valued at the average of the high/low sales price as of the grant date less the present value of the expected distribution stream over the vesting period using a risk-free interest rate. We record the expense for each Service Award on a straight-line basis over the requisite period for the entire award (that is, over the requisite service period of the last separately vesting portion of the award), ensuring that the amount of compensation cost recognized at any date at least equals the portion of the grant-date value of the award that is vested at that date.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Policies)	12 Months Ended
	Mar. 31, 2019
Revenue from Contract with Customer [Abstract]
Revenue, Transaction Price Measurement, Tax Exclusion	Furthermore, under this standard we made an accounting policy election to exclude from the measurement of the transaction price all taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction that we collect from a customer.
Revenue Recognition	Prior to April 1, 2018, we recognized revenue for services and products when all of the following criteria were met under Topic 605: (i) either services have been rendered or products have been delivered or sold; (ii) persuasive evidence of an arrangement existed; (iii) the price for services was fixed or determinable; and (iv) collectibility was reasonably assured. We recorded deferred revenue when we received amounts from our customers but had not yet met the criteria listed above. We recognized deferred revenue in our consolidated statement of operations when the criteria had been met and all services had been rendered. Effective April 1, 2018, we recognize revenue for services and products under revenue contracts as our obligations to either perform services or deliver or sell products under the contracts are satisfied. A performance obligation is a promise in a contract to transfer a distinct good or service to the customer. A contract’s transaction price is allocated to each distinct performance obligation in the contract and is recognized as revenue when, or as, the performance obligation is satisfied. Our revenue contracts in scope under ASC 606 primarily have a single performance obligation. The evaluation of when performance obligations have been satisfied and the transaction price that is allocated to our performance obligations requires significant judgment and assumptions, including our evaluation of the timing of when control of the underlying good or service has transferred to our customers and the relative stand-alone selling price of goods and services provided to customers under contracts with multiple performance obligations. Actual results can vary from those judgments and assumptions. We do not have any material contracts with multiple performance obligations or under which we receive material amounts of non-cash consideration at March 31, 2018. Our costs to obtain or fulfill our revenue contracts were not material as of March 31, 2019 . The majority of our revenue agreements are within scope under ASC 606 and the remainder of our revenue comes from contracts that are accounted for as derivatives under ASC 815 or that contain nonmonetary exchanges or leases and are in scope under Topics 845 and 840, respectively. See Note 12 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Refined and Renewables segment includes $4.2 million of net gains related to changes in the mark-to-market value of these arrangements recorded during the year ended March 31, 2019 . Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 to 60 days. In instances where the timing of revenue recognition differs from the timing of invoicing, we have determined our contracts generally do not include a significant financing component. The primary purpose of our invoicing terms is to allow customers to secure the right to reserve the product or storage capacity to be received or used at a later date, not to receive financing from our customers or to provide customers with financing. We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. We include amounts billed to customers for shipping and handling costs in revenues in our consolidated statements of operations. Crude Oil Logistics Performance Obligations Within the Crude Oil Logistics segment, revenue is disaggregated into two primary revenue streams that include revenue from the sale of commodities and service revenue. For sales of commodities, we are obligated to deliver a predetermined amount of product on a month-to-month basis to our customers. For these types of agreements, revenue is recognized at a point in time based on when the product is delivered and control is transferred to the customer. For revenue received from services rendered, we are obligated to provide throughput services to move product via pipeline, truck, railcar, or marine vessel or to provide terminal maintenance services. In either case, the obligation is satisfied over time utilizing the output method based on each volume of product that is moved from the origination point to the final destination or based on the passage of time. Water Solutions Performance Obligations Within the Water Solutions segment, revenue is disaggregated into two primary revenue streams that include service revenue and commodity sales revenue. For contracts involving disposal services, we accept wastewater and solids for disposal at our facilities. In cases where we have agreed within a contract or are required by law to remove hydrocarbons from the wastewater, the skim oil will be valued as non-cash consideration. Ordinarily, it is required that the fair value of the skim oil is to be estimated at contract inception; however, due to variability of the form of the non-cash consideration, the amount and dollar value is unknown at the contract inception date. Accordingly, ASC 606-10-32-11 allows us to value the skim oil on the date in which the value becomes known. The Water Solutions segment has certain disposal contracts that contain the following types of terms or pricing structures that involve significant judgment that impacts the determination and timing of revenue. • Minimum volume commitments. We receive a shortfall fee if the customer does not deliver a certain amount of volume of wastewater over a specified period of time. At each reporting period, we make a determination as to the likelihood of earning this fee. We recognize revenue from these contracts when (i) actual volumes are received; and (ii) when the likelihood of a customer exercising its remaining rights to make up the deficient volumes under minimum volume commitments becomes remote (also known as the breakage model). • Tiered pricing. For contracts with tiered pricing provisions, the period in which the tiers are earned and settled (i.e. the “reset period”) may vary from monthly to over a period of multiple months. If the tiered pricing is based on a month, we allocate the fee to the distinct daily service to which it relates. If the tiered pricing spans across multiple reporting periods, we estimate the total transaction price at the beginning of each reset period, based on the expected volumes. We revise our estimates of variable consideration at each reporting date throughout each reset period. • Volume discount pricing. Volume discount pricing is a form of variable consideration whereby the customer pays for the volumes delivered on a cumulative basis. Similar to tiered pricing, the period in which the cumulative volumes are earned and settled (i.e. the “reset period”) may vary from daily to over a period of multiple months. If the volume discount is based on a month, we allocate the fee to the distinct daily service to which it relates. If the volume discount period spans across multiple reporting periods, we estimate the total transaction price at the beginning of each reset period, based on the expected volumes. We revise the estimate of variable consideration at each reporting date. For all of our disposal contracts within the Water Solutions segment, revenue will be recognized over time utilizing the output method based on the volume of wastewater or solids we accept from the customer. For contracts that involve the sale of recovered hydrocarbons and freshwater, we will recognize revenue at a point in time, based on when control of the product is transferred to the customer. Liquids Performance Obligations Within the Liquids segment, revenue is disaggregated into two primary revenue streams that include revenue from the sale of commodities and providing services. For commodity sales, we are obligated to deliver a specified amount of product over a specified period of time. For these types of agreements, revenue is recognized at a point in time based on when the product is delivered and control is transferred to the customer. For revenue received from services rendered, we offer a variety of services which include: (i) storage services where product is commingled; (ii) railcar transportation services; (iii) transloading services; and (iv) logistics services. We are obligated to provide these services over a predetermined period of time. Revenue from service contracts is recognized at a point in time upon the transfer of control each month. All revenue from services is recognized over time utilizing the output method based on volumes stored or moved. Refined Products and Renewables Performance Obligations The Refined Products and Renewables segment has one distinct revenue stream, which is revenue from commodity sales. In these agreements, we are obligated to sell a predetermined amount of product over a specified period of time. Revenue for all commodity sales is recognized at a point in time once the customer has lifted the agreed-upon volumes. Remaining Performance Obligations

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Schedule of accounts receivable	Our accounts receivable consist of the following at the dates indicated: March 31, 2019 March 31, 2018 Segment Gross Allowance for Net Gross Allowance for Net (in thousands) Crude Oil Logistics $ 514,243 $ (15 ) $ 514,228 $ 404,865 $ — $ 404,865 Water Solutions 57,526 (3,157 ) 54,369 59,958 (2,952 ) 57,006 Liquids 134,050 (177 ) 133,873 131,006 (20 ) 130,986 Refined Products and Renewables 295,984 (667 ) 295,317 228,574 (879 ) 227,695 Corporate and Other 416 — 416 — — — Total $ 1,002,219 $ (4,016 ) $ 998,203 $ 824,403 $ (3,851 ) $ 820,552
Schedule of changes in the allowance for doubtful accounts	Changes in the allowance for doubtful accounts are as follows for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Allowance for doubtful accounts, beginning of period $ (3,851 ) $ (3,604 ) $ (5,340 ) Provision for doubtful accounts (381 ) (584 ) 739 Write off of uncollectible accounts 216 337 997 Allowance for doubtful accounts, end of period $ (4,016 ) $ (3,851 ) $ (3,604 ) Amounts in the tables above do not include accounts receivable or allowance for doubtful accounts related to TPSL, as these amounts have been classified as current assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the tables above do not include accounts receivable or allowance for doubtful accounts related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of inventories	Inventories consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Crude oil $ 51,359 $ 77,351 Natural gas liquids: Propane 33,478 38,910 Butane 15,294 12,613 Other 7,482 6,515 Refined products and renewables: Diesel 9,186 12,752 Ethanol 14,650 5,542 Biodiesel 4,679 7,966 Total $ 136,128 $ 161,649 Amounts in the table above do not include inventory related to Mid-Con, Gas Blending and TPSL, as these amounts have been classified as current assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include inventory related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of investments in unconsolidated entities	Our investments in unconsolidated entities consist of the following at the dates indicated: Ownership Date Acquired March 31, Entity Segment Interest (1) or Formed 2019 2018 (in thousands) Water services company (2) Water Solutions 50% August 2018 $ 920 $ — Natural gas liquids terminal company (3) Liquids 50% March 2019 207 — Water treatment and disposal facility (4) Water Solutions —% August 2015 — 2,094 E Energy Adams, LLC (5) Refined Products and Renewables —% December 2013 — 15,142 Victory Propane (6) Corporate and Other —% April 2015 — — Total $ 1,127 $ 17,236 (1) Ownership interest percentages are at March 31, 2019 . (2) This is an investment in an unincorporated joint venture that we acquired as part of an acquisition in August 2018. See Note 4 for a further discussion. (3) This is an investment in an unincorporated joint venture that we acquired as part of an acquisition in March 2019. See Note 4 for a further discussion. (4) This is an investment in an unincorporated joint venture. On February 28, 2019, we sold this investment as part of the sale of our South Pecos water disposal business. See Note 16 for a further discussion. (5) On May 3, 2018, we sold our previously held 20% interest in E Energy Adams, LLC for net proceeds of $18.6 million and recorded a gain on disposal of $3.0 million during the year ended March 31, 2019 within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. (6) On August 14, 2018, we sold our previously held 50% interest in Victory Propane. See Note 13 for a further discussion. Combined summarized financial information for all of our unconsolidated entities is as follows for the dates and periods indicated: Balance sheets: March 31, 2019 2018 (in thousands) Current assets $ 1,328 $ 24,431 Noncurrent assets $ 519 $ 99,164 Current liabilities $ 178 $ 16,787 Noncurrent liabilities $ — $ 10,620 Statements of operations: March 31, 2019 2018 2017 (in thousands) Revenues $ 21,036 $ 182,820 $ 180,632 Cost of sales $ 9,919 $ 114,890 $ 114,316 Net income $ 5,506 $ 26,438 $ 19,462 At March 31, 2019 , cumulative equity earnings and cumulative distributions of our unconsolidated entities since they were acquired were $1.9 million and $3.0 million , respectively.
Schedule of other noncurrent assets	Other noncurrent assets consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Loan receivable (1) $ 19,474 $ 29,463 Line fill (2) 33,437 34,897 Minimum shipping fees - pipeline commitments (3) 23,494 88,757 Other 37,452 49,837 Total $ 113,857 $ 202,954 (1) Represents the noncurrent portion of a loan receivable associated with our financing of the construction of a natural gas liquids facility that is utilized by a third party and the noncurrent portion of a loan receivable with Victory Propane (see Note 13). (2) Represents minimum volumes of product we are required to leave on certain third-party owned pipelines under long-term shipment commitments. At March 31, 2019 , line fill consisted of 335,069 barrels of crude oil and 262,000 barrels of propane. At March 31, 2018 , line fill consisted of 360,425 barrels of crude oil and 262,000 barrels of propane. Line fill held in pipelines we own is included within property, plant and equipment (see Note 5). (3) Represents the minimum shipping fees paid in excess of volumes shipped, or deficiency credits, for two contracts with crude oil pipeline operators. This amount can be recovered when volumes shipped exceed the minimum monthly volume commitment (see Note 9). During the three months ended June 30, 2018, we entered into a definitive agreement, as described further in Note 13, in which we agreed to provide the benefit of our deficiency credit under one of these contracts. As a result of providing this benefit to the third party, we wrote off $67.7 million of these deficiency credits and recorded a loss within loss (gain) on disposal or impairment of assets, net . Under the remaining other contract for which we have the future benefit, we currently have 13 months in which to ship the excess volumes. Amounts in the table above do not include other noncurrent assets related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include other noncurrent assets related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of accrued expenses and other payables	Accrued expenses and other payables consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Accrued compensation and benefits $ 19,312 $ 17,778 Excise and other tax liabilities 10,481 8,279 Derivative liabilities 4,960 8,321 Accrued interest 24,882 39,947 Product exchange liabilities 5,945 1,116 Gavilon legal matter settlement (Note 9) 12,500 — Deferred gain on sale of general partner interest in TLP (1) — 30,113 Other 29,679 31,688 Total $ 107,759 $ 137,242 (1) See Note 15 for a discussion of the accounting for the deferred gain upon adoption of ASC 606. Amounts in the table above do not include accrued expenses and other payables related to TPSL and Mid-Con and Gas Blending derivative liabilities, as these amounts have been classified as current liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include accrued expenses and other payables related to our former Retail Propane segment, as these amounts have been classified as current liabilities held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of redeemable noncontrolling interest	The following table summarizes changes in our redeemable noncontrolling interest in our consolidated balance sheets (in thousands): Balance at March 31, 2017 $ 3,072 Net income attributable to redeemable noncontrolling interest 1,030 Redeemable noncontrolling interest valuation adjustment 5,825 Balance at March 31, 2018 9,927 Net loss attributable to redeemable noncontrolling interest (446 ) Redeemable noncontrolling interest valuation adjustment 3,349 Disposal of redeemable noncontrolling interest (12,830 ) Balance at March 31, 2019 $ —

Income (Loss) Per Common Unit (

Income (Loss) Per Common Unit (Tables)	12 Months Ended
	Mar. 31, 2019
Earnings Per Unit [Abstract]
Schedule of weighted average number of units	The following table presents our calculation of basic and diluted weighted average common units outstanding for the periods indicated: Year Ended March 31, 2019 2018 2017 Weighted average common units outstanding during the period: Common units - Basic 123,017,064 120,991,340 108,091,486 Effect of Dilutive Securities: Performance awards — — 173,087 Warrants — — 3,586,048 Common units - Diluted 123,017,064 120,991,340 111,850,621 For the year ended March 31, 2019 , the Service Awards (as defined herein), warrants and the Class A Preferred Units (as defined herein) were considered antidilutive. Due to the termination of the Performance Award plan (see Note 10), there were no outstanding Performance Awards (as defined herein) as of March 31, 2019. For the year ended March 31, 2018, the Service Awards, Performance Awards, warrants and Class A Preferred Units were considered antidilutive. For the year ended March 31, 2017, the Service Awards and Class A Preferred Units were considered antidilutive.
Schedule of income (loss) per common unit	Our income (loss) per common unit is as follows for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands, except unit and per unit amounts) (Loss) income from continuing operations $ (79,455 ) $ (22,477 ) $ 115,547 Less: Continuing operations loss (income) attributable to noncontrolling interests 20,206 (240 ) (6,832 ) Net (loss) income from continuing operations attributable to NGL Energy Partners LP (59,249 ) (22,717 ) 108,715 Less: Distributions to preferred unitholders (1) (111,936 ) (59,697 ) (30,142 ) Less: Continuing operations net loss (income) allocated to general partner (2) 32 (53 ) (204 ) Less: Repurchase of warrants (3) — (349 ) — Net (loss) income from continuing operations allocated to common unitholders $ (171,153 ) $ (82,816 ) $ 78,369 Income (loss) from discontinued operations, net of tax $ 418,850 $ (47,128 ) $ 28,327 Less: Discontinued operations loss (income) attributable to redeemable noncontrolling interests 446 (1,030 ) — Less: Discontinued operations (income) loss allocated to general partner (2) (419 ) 48 (28 ) Net income (loss) from discontinued operations allocated to common unitholders $ 418,877 $ (48,110 ) $ 28,299 Net income (loss) allocated to common unitholders $ 247,724 $ (130,926 ) $ 106,668 Basic income (loss) per common unit (Loss) income from continuing operations $ (1.39 ) $ (0.68 ) $ 0.73 Income (loss) from discontinued operations, net of tax $ 3.41 $ (0.40 ) $ 0.26 Net income (loss) $ 2.01 $ (1.08 ) $ 0.99 Diluted income (loss) per common unit (Loss) income from continuing operations $ (1.39 ) $ (0.68 ) $ 0.70 Income (loss) from discontinued operations, net of tax $ 3.41 $ (0.40 ) $ 0.25 Net income (loss) $ 2.01 $ (1.08 ) $ 0.95 Basic weighted average common units outstanding 123,017,064 120,991,340 108,091,486 Diluted weighted average common units outstanding 123,017,064 120,991,340 111,850,621 (1) This amount includes the distribution to preferred unitholders as well as the accretion for the beneficial conversion, as discussed further in Note 10. (2) Net (income) loss allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights. (3) This amount represents the excess of the repurchase price over the fair value of the warrants, as discussed further in Note 10.

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Mar. 31, 2019
Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Schedule of the fair values of the assets acquired and liabilities assumed	The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Property, plant and equipment $ 7,123 Goodwill 23,570 Intangible assets 64,015 Investments in unconsolidated entities 2,060 Current liabilities (276 ) Other noncurrent liabilities (19,288 ) Fair value of net assets acquired $ 77,204 Property, plant and equipment $ 36,590 Goodwill 50,619 Intangible assets 29,287 Current liabilities (10 ) Other noncurrent liabilities (410 ) Fair value of net assets acquired $ 116,076
Liquids Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Schedule of the fair values of the assets acquired and liabilities assumed	The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Inventories $ 15,370 Other current assets 667 Property, plant and equipment 42,413 Goodwill 20,472 Intangible assets 26,900 Investments in unconsolidated entities 204 Current liabilities (2,128 ) Other noncurrent liabilities (524 ) Fair value of net assets acquired $ 103,374
Refined Products Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Schedule of the fair values of the assets acquired and liabilities assumed	The following table summarizes the transaction close date preliminary estimates of the fair values for the assets acquired and liabilities assumed (in thousands): Inventories $ 327 Other current assets 85 Property, plant and equipment 9,986 Goodwill 1,328 Intangible assets 4,600 Current liabilities (4 ) Fair value of net assets acquired $ 16,322

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Mar. 31, 2019
Property, Plant and Equipment [Abstract]
Schedule of property, plant and equipment	Our property, plant and equipment consists of the following at the dates indicated: Estimated March 31, Description Useful Lives 2019 2018 (in years) (in thousands) Natural gas liquids terminal and storage assets 2 - 30 $ 280,106 $ 238,487 Pipeline and related facilities 30 - 40 243,799 243,616 Vehicles and railcars 3 - 25 124,948 121,159 Water treatment facilities and equipment 3 - 30 704,666 601,139 Crude oil tanks and related equipment 2 - 30 225,476 218,588 Barges and towboats 5 - 30 103,735 92,712 Information technology equipment 3 - 7 31,831 29,521 Buildings and leasehold improvements 3 - 40 143,711 147,110 Land 62,379 51,816 Tank bottoms and line fill (1) 20,071 20,118 Other 3 - 20 14,870 11,646 Construction in progress 290,805 77,596 2,246,397 1,853,508 Accumulated depreciation (417,457 ) (341,222 ) Net property, plant and equipment $ 1,828,940 $ 1,512,286 (1) Tank bottoms, which are product volumes required for the operation of storage tanks, are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. Line fill, which represents our portion of the product volume required for the operation of the proportionate share of a pipeline we own, is recorded at historical cost. Amounts in the table above do not include property, plant and equipment and accumulated depreciation related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include property, plant and equipment and accumulated depreciation related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of depreciation expense and capitalized interest expense	The following table summarizes depreciation expense and capitalized interest expense for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Depreciation expense $ 101,515 $ 99,954 $ 89,848 Capitalized interest expense $ 482 $ 182 $ 6,887 Amounts in the table above do not include depreciation expense and capitalized interest related to TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ).
Schedule of (gain) loss on sale of assets	We record (gains) losses from the sales of property, plant and equipment and any write-downs in value due to impairment within loss (gain) on disposal or impairment of assets, net in our consolidated statement of operations. The following table summarizes (gains) losses on the disposal or impairment of property, plant and equipment by segment for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Crude Oil Logistics (1) $ 3,489 $ (3,144 ) $ 8,124 Water Solutions 3,067 8,117 7,169 Liquids 993 639 92 Corporate — 8 (1 ) Total $ 7,549 $ 5,620 $ 15,384 (1) Amount for the year ended March 31, 2018 primarily relates to a gain related to the sale of excess pipe, partially offset by losses from the disposal of certain assets and the write-down of other assets. Amount for the year ended March 31, 2017 primarily relates to losses from the sale of certain assets, including excess pipe.

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Mar. 31, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of changes in goodwill by segment	The following table summarizes changes in goodwill by segment for the periods indicated (in thousands): Crude Oil Water Liquids Refined Total (in thousands) Balances at March 31, 2017 $ 579,846 $ 424,270 $ 266,046 $ 17,050 $ 1,287,212 Revisions to acquisition accounting — 195 — — 195 Impairment — — (116,877 ) — (116,877 ) Balances at March 31, 2018 579,846 424,465 149,169 17,050 1,170,530 Acquisitions (Note 4) — 74,189 20,472 — 94,661 Disposals (Note 16) — (88,515 ) — — (88,515 ) Impairment — — (66,220 ) — (66,220 ) Balances at March 31, 2019 $ 579,846 $ 410,139 $ 103,421 $ 17,050 $ 1,110,456 Amounts in the table above do not include goodwill that was allocated to TPSL and Gas Blending, as the amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ).

Intangible Assets (Tables)

Intangible Assets (Tables)	12 Months Ended
	Mar. 31, 2019
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of finite-lived intangible assets	Our intangible assets consist of the following at the dates indicated: March 31, 2019 March 31, 2018 Description Amortizable Lives Gross Carrying Amount Accumulated Amortization Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 742,832 $ (369,983 ) $ 372,849 $ 718,764 $ (328,666 ) $ 390,098 Customer commitments 10 310,000 (74,917 ) 235,083 310,000 (43,917 ) 266,083 Pipeline capacity rights 30 7,799 (1,387 ) 6,412 7,799 (1,127 ) 6,672 Rights-of-way and easements 1 - 40 73,409 (4,509 ) 68,900 63,995 (3,214 ) 60,781 Water rights 14 64,868 (3,018 ) 61,850 — — — Executory contracts and other agreements 3 - 30 47,230 (17,212 ) 30,018 42,919 (15,424 ) 27,495 Non-compete agreements 2 - 32 12,723 (2,570 ) 10,153 5,465 (706 ) 4,759 Debt issuance costs (1) 5 42,345 (29,521 ) 12,824 40,992 (24,593 ) 16,399 Total amortizable 1,301,206 (503,117 ) 798,089 1,189,934 (417,647 ) 772,287 Non-amortizable: Trade names 2,800 — 2,800 2,800 — 2,800 Total $ 1,304,006 $ (503,117 ) $ 800,889 $ 1,192,734 $ (417,647 ) $ 775,087 (1) Includes debt issuance costs related to the Revolving Credit Facility (as defined herein). Debt issuance costs related to fixed-rate notes are reported as a reduction of the carrying amount of long-term debt. Amounts in the table above do not include intangible assets and accumulated amortization related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include intangible assets and accumulated amortization related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of indefinite-lived intangible assets	Our intangible assets consist of the following at the dates indicated: March 31, 2019 March 31, 2018 Description Amortizable Lives Gross Carrying Amount Accumulated Amortization Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 742,832 $ (369,983 ) $ 372,849 $ 718,764 $ (328,666 ) $ 390,098 Customer commitments 10 310,000 (74,917 ) 235,083 310,000 (43,917 ) 266,083 Pipeline capacity rights 30 7,799 (1,387 ) 6,412 7,799 (1,127 ) 6,672 Rights-of-way and easements 1 - 40 73,409 (4,509 ) 68,900 63,995 (3,214 ) 60,781 Water rights 14 64,868 (3,018 ) 61,850 — — — Executory contracts and other agreements 3 - 30 47,230 (17,212 ) 30,018 42,919 (15,424 ) 27,495 Non-compete agreements 2 - 32 12,723 (2,570 ) 10,153 5,465 (706 ) 4,759 Debt issuance costs (1) 5 42,345 (29,521 ) 12,824 40,992 (24,593 ) 16,399 Total amortizable 1,301,206 (503,117 ) 798,089 1,189,934 (417,647 ) 772,287 Non-amortizable: Trade names 2,800 — 2,800 2,800 — 2,800 Total $ 1,304,006 $ (503,117 ) $ 800,889 $ 1,192,734 $ (417,647 ) $ 775,087 (1) Includes debt issuance costs related to the Revolving Credit Facility (as defined herein). Debt issuance costs related to fixed-rate notes are reported as a reduction of the carrying amount of long-term debt. Amounts in the table above do not include intangible assets and accumulated amortization related to TPSL, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the table above do not include intangible assets and accumulated amortization related to our former Retail Propane segment, as these amounts have been classified as noncurrent assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of amortization expense	Amortization expense is as follows for the periods indicated: Year Ended March 31, Recorded In 2019 2018 2017 (in thousands) Depreciation and amortization $ 110,458 $ 108,444 $ 89,765 Cost of sales 486 966 1,994 Interest expense 4,928 4,568 4,471 Total $ 115,872 $ 113,978 $ 96,230 Amounts in the table above do not include amortization expense related to TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ).
Schedule of expected amortization of intangible assets	Expected amortization of our intangible assets is as follows (in thousands): Year Ending March 31, 2020 $ 116,626 2021 104,512 2022 91,674 2023 83,654 2024 77,514 Thereafter 324,109 Total $ 798,089

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Mar. 31, 2019
Long-Term Debt
Schedule of long-term debt	Our long-term debt consists of the following at the dates indicated: March 31, 2019 March 31, 2018 Face Unamortized Book Face Unamortized Book (in thousands) Revolving credit facility: Expansion capital borrowings $ 275,000 $ — $ 275,000 $ — $ — $ — Working capital borrowings 896,000 — 896,000 969,500 — 969,500 Senior unsecured notes: 5.125% Notes due 2019 ("2019 Notes") — — — 353,424 (1,653 ) 351,771 6.875% Notes due 2021 ("2021 Notes") — — — 367,048 (4,499 ) 362,549 7.500% Notes due 2023 ("2023 Notes") 607,323 (6,916 ) 600,407 615,947 (8,542 ) 607,405 6.125% Notes due 2025 ("2025 Notes") 389,135 (5,092 ) 384,043 389,135 (5,951 ) 383,184 Other long-term debt 5,331 — 5,331 5,977 — 5,977 2,172,789 (12,008 ) 2,160,781 2,701,031 (20,645 ) 2,680,386 Less: Current maturities 648 — 648 646 — 646 Long-term debt $ 2,172,141 $ (12,008 ) $ 2,160,133 $ 2,700,385 $ (20,645 ) $ 2,679,740 (1) Debt issuance costs related to the Revolving Credit Facility are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt. Amounts in the table above do not include long-term debt related to our former Retail Propane segment, as these amounts have been classified as liabilities held for sale within our March 31, 2018 consolidated balance sheet (see Note 17 ).
Schedule of future amortization expense of debt issuance costs	Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2020 $ 2,371 2021 2,367 2022 2,367 2023 2,367 2024 1,744 Thereafter 792 Total $ 12,008
Schedule of financial covenants in Credit Agreement	The following table summarizes the debt covenant levels specified in the Credit Agreement as of March 31, 2019 (as modified on February 6, 2019): Senior Secured Interest Total Leverage Period Beginning Leverage Ratio (1) Leverage Ratio (1) Coverage Ratio (2) Indebtedness Ratio (1) March 31, 2019 4.50 3.25 2.75 6.50 September 30, 2019 4.50 3.25 2.75 6.25 March 31, 2020 and thereafter 4.50 3.25 2.75 6.00 (1) Represents the maximum ratio for the period presented. (2) Represents the minimum ratio for the period presented.
Schedule of maturities of long-term debt	Debt Maturity Schedule The scheduled maturities of our long-term debt are as follows at March 31, 2019 : Year Ending March 31, Revolving Senior Unsecured Notes Other Long-Term Debt Total (in thousands) 2020 $ — $ — $ 648 $ 648 2021 — — 4,683 4,683 2022 1,171,000 — — 1,171,000 2023 — — — — 2024 — 607,323 — 607,323 Thereafter — 389,135 — 389,135 Total $ 1,171,000 $ 996,458 $ 5,331 $ 2,172,789
Senior secured notes
Long-Term Debt
Schedule of repurchases	The following table summarizes repurchases of Senior Secured Notes for the period indicated: Year Ended March 31, 2018 (in thousands) Senior Secured Notes Notes repurchased $ 230,500 Cash paid (excluding payments of accrued interest) $ 250,179 Loss on early extinguishment of debt (1) $ (23,971 ) (1) Loss on the early extinguishment of debt for the Senior Secured Notes during the year ended March 31, 2018 is inclusive of the write off of debt issuance costs of $4.3 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations.
Redemptions | Senior unsecured notes
Long-Term Debt
Schedule of repurchases	The following table summarizes redemptions of Senior Unsecured Notes for the period indicated: Year Ended March 31, 2019 (in thousands) 2019 Notes (1) Notes redeemed $ 328,005 Cash paid (excluding payments of accrued interest) $ 329,719 Loss on early extinguishment of debt $ (2,113 ) 2021 Notes (2) Notes redeemed $ 367,048 Cash paid (excluding payments of accrued interest) $ 373,358 Loss on early extinguishment of debt $ (10,130 ) (1) On March 15, 2019, we redeemed all of the remaining outstanding 2019 Notes. Loss on the early extinguishment of debt for the 2019 Notes during the year ended March 31, 2019 is inclusive of the write off of debt issuance costs of $0.4 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) On October 16, 2018, we redeemed all of the remaining outstanding 2021 Notes. Loss on the early extinguishment of debt for the 2021 Notes during the year ended March 31, 2019 is inclusive of the write off of debt issuance costs of $3.8 million . The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations.
Repurchases | Senior unsecured notes
Long-Term Debt
Schedule of repurchases	The following table summarizes repurchases of Senior Unsecured Notes for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) 2019 Notes Notes repurchased $ 25,419 $ 26,034 $ 9,009 Cash paid (excluding payments of accrued interest) $ 25,406 $ 26,002 $ 7,099 (Loss) gain on early extinguishment of debt (1) $ (34 ) $ (140 ) $ 1,759 2021 Notes Notes repurchased $ — $ — $ 21,241 Cash paid (excluding payments of accrued interest) $ — $ — $ 14,094 Gain on early extinguishment of debt (2) $ — $ — $ 6,748 2023 Notes Notes repurchased $ 8,624 $ 84,053 $ — Cash paid (excluding payments of accrued interest) $ 8,575 $ 83,967 $ — Loss on early extinguishment of debt (3) $ (63 ) $ (1,136 ) $ — 2025 Notes Notes repurchased $ — $ 110,865 $ — Cash paid (excluding payments of accrued interest) $ — $ 107,050 $ — Gain on early extinguishment of debt (4) $ — $ 2,046 $ — (1) (Loss) gain on early extinguishment of debt for the 2019 Notes during the years ended March 31, 2019, 2018 and 2017 is inclusive of the write off of debt issuance costs of less than $0.1 million $0.2 million and $0.2 million , respectively. The (loss) gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) Gain on early extinguishment of debt for the 2021 Notes during the year ended March 31, 2017 is inclusive of the write off of debt issuance costs of $0.4 million . The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (3) Loss on early extinguishment of debt for the 2023 Notes during the years ended March 31, 2019 and 2018 is inclusive of the write off of debt issuance costs of $0.1 million and $1.2 million , respectively. The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (4) Gain on early extinguishment of debt for the 2025 Notes during the year ended March 31, 2018 is inclusive of the write off of debt issuance costs of $1.8 million . The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of change in asset retirement obligation	The following table summarizes changes in our asset retirement obligation, which is reported within other noncurrent liabilities in our consolidated balance sheets (in thousands): Balance at March 31, 2017 $ 8,181 Liabilities incurred 592 Liabilities assumed in acquisitions 21 Liabilities settled (549 ) Accretion expense 888 Balance at March 31, 2018 9,133 Liabilities incurred 586 Liabilities assumed in acquisitions 438 Liabilities associated with disposed assets (1) (585 ) Liabilities settled (546 ) Accretion expense 697 Balance at March 31, 2019 $ 9,723 (1) This amount primarily relates to the sales of our Bakken and South Pecos water disposal businesses (see Note 16 ).
Schedule of future minimum lease payments under contractual commitments	The following table summarizes future minimum lease payments under these agreements at March 31, 2019 (in thousands): Year Ending March 31, 2020 $ 78,348 2021 60,417 2022 43,259 2023 29,252 2024 18,341 Thereafter 41,845 Total $ 271,462 Amounts in the table above do not include future minimum lease payments related to Mid-Con, Gas Blending and TPSL as Mid-Con, Gas Blending and TPSL have been classified as discontinued operations in our consolidated statements of operations (see Note 1 and Note 17 ).
Schedule of outstanding purchase commitments	At March 31, 2019 , we had the following commodity purchase commitments (in thousands): Crude Oil (1) Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Purchase Commitments: 2020 $ 60,227 1,040 $ 5,033 7,545 2021 — — 265 378 Total $ 60,227 1,040 $ 5,298 7,923 Index-Price Commodity Purchase Commitments: 2020 $ 1,703,112 30,363 $ 564,013 1,023,998 2021 526,420 10,227 1,199 2,152 2022 411,071 8,264 — — 2023 269,990 5,482 — — 2024 200,022 4,110 — — Total $ 3,110,615 58,446 $ 565,212 1,026,150 (1) Our crude oil index-price purchase commitments exceed our crude oil index-price sales commitments (presented below) due primarily to our long-term purchase commitments for crude oil that we purchase and ship on the Grand Mesa Pipeline. As these purchase commitments are deliver-or-pay contracts, whereby our counterparty is required to pay us for any volumes not delivered, we have not entered into corresponding long-term sales contracts for volumes we may not receive.
Schedule of outstanding sales commitments	At March 31, 2019 , we had the following commodity sale commitments (in thousands): Crude Oil Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Sale Commitments: 2020 $ 63,759 1,090 $ 45,626 52,766 2021 — — 1,395 1,580 2022 — — 86 100 Total $ 63,759 1,090 $ 47,107 54,446 Index-Price Commodity Sale Commitments: 2020 $ 1,240,074 20,500 $ 594,877 778,454 2021 — — 1,634 2,183 Total $ 1,240,074 20,500 $ 596,511 780,637

Equity (Tables)

Equity (Tables)	12 Months Ended
	Mar. 31, 2019
Equity
Schedule of distributions declared	The following table summarizes distributions declared on our common units during the last three fiscal years: Date Declared Record Date Payment Date Amount Per Unit Amount Paid to Limited Partners Amount Paid to General Partner (in thousands) (in thousands) April 21, 2016 May 3, 2016 May 13, 2016 $ 0.3900 $ 40,626 $ 70 July 21, 2016 August 4, 2016 August 12, 2016 $ 0.3900 $ 41,146 $ 71 October 20, 2016 November 4, 2016 November 14, 2016 $ 0.3900 $ 41,907 $ 72 January 19, 2017 February 3, 2017 February 14, 2017 $ 0.3900 $ 42,923 $ 74 April 24, 2017 May 8, 2017 May 15, 2017 $ 0.3900 $ 46,870 $ 80 July 20, 2017 August 4, 2017 August 14, 2017 $ 0.3900 $ 47,460 $ 81 October 19, 2017 November 6, 2017 November 14, 2017 $ 0.3900 $ 47,000 $ 81 January 23, 2018 February 6, 2018 February 14, 2018 $ 0.3900 $ 47,223 $ 81 April 24, 2018 May 7, 2018 May 15, 2018 $ 0.3900 $ 47,374 $ 82 July 24, 2018 August 8, 2018 August 14, 2018 $ 0.3900 $ 47,600 $ 82 October 23, 2018 November 8, 2018 November 14, 2018 $ 0.3900 $ 48,260 $ 83 January 22, 2019 February 6, 2019 February 14, 2019 $ 0.3900 $ 48,373 $ 83 April 24, 2019 May 7, 2019 May 15, 2019 $ 0.3900 $ 49,127 $ 85
Service awards
Equity
Schedule of awards activity	The following table summarizes the Service Award activity during the years ended March 31, 2019 , 2018 and 2017 : Unvested Service Award units at March 31, 2016 2,297,132 Units granted 3,124,600 Units vested and issued (2,350,082 ) Units forfeited (363,150 ) Unvested Service Award units at March 31, 2017 2,708,500 Units granted 1,964,911 Units vested and issued (2,260,011 ) Units forfeited (134,525 ) Unvested Service Award units at March 31, 2018 2,278,875 Units granted 3,141,993 Units vested and issued (2,833,968 ) Units forfeited (278,500 ) Unvested Service Award units at March 31, 2019 2,308,400
Schedule of scheduled vesting of awards	The following table summarizes the scheduled vesting of our unvested Service Award units at March 31, 2019 : Year Ending March 31, Number of Units 2020 1,005,725 2021 869,425 2022 433,250 Total 2,308,400
Schedule of estimated equity-based expense to be recorded on the awards granted	The following table summarizes the estimated future expense we expect to record on the unvested Service Award units at March 31, 2019 (in thousands): Year Ending March 31, 2020 $ 8,168 2021 4,154 2022 1,350 Total $ 13,672
Performance awards
Equity
Schedule of awards activity	The following table summarizes the Performance Award activity during the years ended March 31, 2019 , 2018 and 2017 : Unvested Performance Award units at March 31, 2016 637,382 Units granted 932,309 Units forfeited (380,691 ) Unvested Performance Award units at March 31, 2017 1,189,000 Units granted 224,000 Units forfeited (496,000 ) Unvested Performance Award units at March 31, 2018 917,000 Units forfeited (445,500 ) Units canceled (471,500 ) Unvested Performance Award units at March 31, 2019 —
Class A Convertible Preferred Units
Equity
Schedule of distributions declared	The following table summarizes distributions declared on our Class A Preferred Units during the last three fiscal years: Date Declared Payment Date Amount Paid to Class A (in thousands) July 21, 2016 August 12, 2016 $ 1,795 October 20, 2016 November 14, 2016 $ 6,449 January 19, 2017 February 14, 2017 $ 6,449 April 24, 2017 May 15, 2017 $ 6,449 July 20, 2017 August 14, 2017 $ 6,449 October 19, 2017 November 14, 2017 $ 6,449 January 23, 2018 February 14, 2018 $ 6,449 April 24, 2018 May 15, 2018 $ 6,449 July 24, 2018 August 14, 2018 $ 6,449 October 23, 2018 November 14, 2018 $ 6,449 January 22, 2019 February 14, 2019 $ 6,449 April 24, 2019 May 10, 2019 $ 4,034
Class B Perpetual Preferred Units
Equity
Schedule of distributions declared	The following table summarizes distributions declared on our Class B Preferred Units during the last two fiscal years: Date Declared Record Date Payment Date Amount Paid to Class B (in thousands) September 18, 2017 September 29, 2017 October 16, 2017 $ 5,670 December 19, 2017 December 29, 2017 January 15, 2018 $ 4,725 March 19, 2018 April 2, 2018 April 16, 2018 $ 4,725 June 19, 2018 July 2, 2018 July 16, 2018 $ 4,725 September 12, 2018 October 1, 2018 October 15, 2018 $ 4,725 December 17, 2018 December 31, 2018 January 15, 2019 $ 4,725 March 15, 2019 April 1, 2019 April 15, 2019 $ 4,725

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Schedule of estimated fair value measurements of assets and liabilities	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported in our consolidated balance sheet at the dates indicated: March 31, 2019 March 31, 2018 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 3,754 $ (1,349 ) $ 2,835 $ (4,406 ) Level 2 measurements 8,882 (5,119 ) 7,013 (11,503 ) 12,636 (6,468 ) 9,848 (15,909 ) Netting of counterparty contracts (1) (1,577 ) 1,577 (664 ) 664 Net cash collateral provided (held) 1,740 (208 ) (4,718 ) 3,742 Commodity derivatives $ 12,799 $ (5,099 ) $ 4,466 $ (11,503 ) (1) Relates to commodity derivative assets and liabilities that are expected to be net settled on an exchange or through a netting arrangement with the counterparty. Our physical contracts that do not qualify as normal purchase normal sale transactions are not subject to such netting arrangements.
Schedule of location of commodity derivative assets and liabilities reported in the consolidated balance sheets	The following table summarizes the accounts that include our commodity derivative assets and liabilities in our consolidated balance sheets at the dates indicated: March 31, 2019 2018 (in thousands) Prepaid expenses and other current assets $ 12,799 $ 4,466 Accrued expenses and other payables (4,960 ) (8,321 ) Other noncurrent liabilities (139 ) (3,182 ) Net commodity derivative asset (liability) $ 7,700 $ (7,037 )
Schedule of open commodity derivative contract positions	The following table summarizes our open commodity derivative contract positions at the dates indicated. We do not account for these derivatives as hedges. Contracts Settlement Period Net Long Fair Value (in thousands) At March 31, 2019: Crude oil fixed-price (1) April 2019–December 2020 (1,961 ) 979 Propane fixed-price (1) April 2019–March 2020 198 608 Refined products fixed-price (1) April 2019–January 2021 (177 ) 376 Other April 2019–March 2022 4,205 6,168 Net cash collateral provided 1,532 Net commodity derivative asset $ 7,700 At March 31, 2018: Cross-commodity (2) April 2018–March 2019 155 $ (430 ) Crude oil fixed-price (1) April 2018–December 2019 (1,376 ) $ (8,960 ) Crude oil index (1) April 2018–April 2018 (10 ) $ (6 ) Propane fixed-price (1) April 2018–February 2019 14 1,849 Refined products fixed-price (1) April 2018–January 2020 (229 ) 215 Refined products index (1) April 2018–April 2018 (4 ) (17 ) Other April 2018–March 2022 1,288 (6,061 ) Net cash collateral held (976 ) Net commodity derivative liability $ (7,037 ) (1) We may have fixed price physical purchases, including inventory, offset by floating price physical sales or floating price physical purchases offset by fixed price physical sales. These contracts are derivatives we have entered into as an economic hedge against the risk of mismatches between fixed and floating price physical obligations. (2) We may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. These contracts are derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price. Amounts in the tables above do not include commodity derivative contract positions related to Mid-Con, Gas Blending and TPSL, as these amounts have been classified as current and noncurrent assets and liabilities held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 1 and Note 17 ). In addition, amounts in the tables above do not include commodity derivative contract positions related to our former Retail Propane segment, as these amounts have been classified as current assets held for sale within our March 31, 2018 consolidated balance sheet (see Note 1 and Note 17 ).
Schedule of net gains (losses) from commodity derivatives	The following table summarizes the net gains (losses) recorded from our commodity derivatives to revenues and cost of sales in our consolidated statements of operations for the periods indicated (in thousands): Year Ended March 31, 2019 $ 10,817 2018 $ (41,263 ) 2017 $ (15,376 ) Amounts in the table above do not include net gains (losses) from our commodity derivatives related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented (see Note 1 and Note 17 ).
Schedule of fair value estimates of fixed-rate notes	The following table provides fair values estimates of our fixed-rate notes at March 31, 2019 (in thousands): Senior Unsecured Notes: 2023 Notes $ 626,621 2025 Notes $ 375,126

Segments (Tables)

Segments (Tables)	12 Months Ended
	Mar. 31, 2019
Segment Reporting [Abstract]
Schedule of certain information related to results of operations by segment	The following table summarizes revenues related to our segments. Revenues for reporting periods beginning after April 1, 2018 are presented under Topic 606 (see Note 15 for a further discussion), while prior periods are not adjusted and continue to be reported under the accounting standard in effect for those periods. Transactions between segments are recorded based on prices negotiated between the segments. The “Corporate and Other” category in the table below includes certain corporate expenses that are not allocated to the reportable segments. Year Ended March 31, 2019 2018 (1) 2017 (1) (in thousands) Revenues: Crude Oil Logistics: Topic 606 revenues Crude oil sales $ 3,011,355 $ 2,151,203 $ 1,603,667 Crude oil transportation and other 148,738 122,786 70,027 Non-Topic 606 revenues 12,598 — — Elimination of intersegment sales (36,056 ) (13,914 ) (6,810 ) Total Crude Oil Logistics revenues 3,136,635 2,260,075 1,666,884 Water Solutions: Topic 606 revenues Disposal service fees 217,545 149,114 110,049 Sale of recovered hydrocarbons 72,678 58,948 31,103 Freshwater revenues 2,404 — — Other service revenues 9,017 21,077 18,449 Non-Topic 606 revenues 42 — — Total Water Solutions revenues 301,686 229,139 159,601 Liquids: Topic 606 revenues Propane sales 1,169,117 1,203,486 807,172 Butane sales 628,063 562,066 391,265 Other product sales 592,889 432,570 308,031 Service revenues 26,655 22,548 32,648 Non-Topic 606 revenues 21,608 — — Elimination of intersegment sales (23,291 ) (4,685 ) (1,944 ) Total Liquids revenues 2,415,041 2,215,985 1,537,172 Refined Products and Renewables: Topic 606 revenues Refined products sales 2,535,243 1,874,260 1,405,001 Renewables sales — 373,669 447,232 Service fees and other revenues — (87 ) — Non-Topic 606 revenues 299,190 — — Elimination of intersegment sales — (268 ) (469 ) Total Refined Products and Renewables revenues 2,834,433 2,247,574 1,851,764 Corporate and Other Non-Topic 606 revenues 1,362 1,174 844 Total Corporate and Other revenues 1,362 1,174 844 Total revenues $ 8,689,157 $ 6,953,947 $ 5,216,265 (1) We adopted ASC 606 as of April 1, 2018. Revenue reported in fiscal years 2018 and 2017 has not been changed from its previous presentation. The following table summarizes depreciation and amortization expense and operating income (loss) by segment for the periods indicated. Year Ended March 31, 2019 2018 2017 (in thousands) Depreciation and Amortization: Crude Oil Logistics $ 74,165 $ 80,387 $ 54,144 Water Solutions 108,162 98,623 101,758 Liquids 25,997 24,937 19,163 Refined Products and Renewables 631 672 936 Corporate and Other 3,018 3,779 3,612 Total depreciation and amortization (1) $ 211,973 $ 208,398 $ 179,613 Operating Income (Loss): Crude Oil Logistics $ (7,379 ) $ 122,904 $ (17,475 ) Water Solutions 210,525 (24,231 ) 44,587 Liquids (2,910 ) (93,113 ) 43,252 Refined Products and Renewables 12,198 261,249 243,090 Corporate and Other (85,706 ) (79,474 ) (86,985 ) Total operating income (loss) $ 126,728 $ 187,335 $ 226,469 (1) Amounts do not include amortization expense recorded within interest expense and cost of sales (see Note 7 and Note 8).
Schedule of additions to property, plant and equipment and intangible assets by segment	The following table summarizes additions to property, plant and equipment and intangible assets by segment for the periods indicated. This information has been prepared on the accrual basis, and includes property, plant and equipment and intangible assets acquired in acquisitions. This information below does not include goodwill by segment. Year Ended March 31, 2019 2018 2017 (in thousands) Crude Oil Logistics $ 28,039 $ 36,762 $ 168,053 Water Solutions 567,637 102,261 109,008 Liquids 72,717 25,023 66,864 Corporate and Other 1,819 1,472 2,825 Total $ 670,212 $ 165,518 $ 346,750
Schedule of long-lived assets (consisting of property, plant and equipment, intangible assets and goodwill) and total assets by segment	The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment at the dates indicated: March 31, 2019 2018 (in thousands) Long-lived assets, net: Crude Oil Logistics $ 1,584,636 $ 1,638,558 Water Solutions 1,600,836 1,256,143 Liquids (1) 498,767 501,302 Refined Products and Renewables 29,477 30,384 Corporate and Other 26,569 31,516 Total $ 3,740,285 $ 3,457,903 (1) Includes $0.5 million and $0.6 million of non-US long-lived assets at March 31, 2019 and 2018 , respectively. March 31, 2019 2018 (in thousands) Total assets: Crude Oil Logistics $ 2,237,612 $ 2,285,813 Water Solutions 1,668,292 1,323,171 Liquids (1) 721,008 717,690 Refined Products and Renewables 383,026 341,495 Corporate and Other 77,019 102,211 Assets held for sale 815,536 1,380,742 Total $ 5,902,493 $ 6,151,122 (1) Includes $12.0 million and $27.5 million of non-US total assets at March 31, 2019 and 2018 , respectively. All of the tables above do not include amounts related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified as discontinued operations within our consolidated statements of operations for all periods presented and as held for sale within our March 31, 2019 and 2018 consolidated balance sheets (see Note 17 ).

Transactions with Affiliates (T

Transactions with Affiliates (Tables)	12 Months Ended
	Mar. 31, 2019
Related Party Transactions [Abstract]
Summary of purchase and sales transactions of products and services	The following table summarizes these related party transactions for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Sales to WPX $ 28,026 $ — $ — Purchases from WPX (1) $ 329,525 $ — $ — Sales to SemGroup $ 1,114 $ 606 $ 3,866 Purchases from SemGroup $ 4,395 $ 5,034 $ 12,254 Sales to entities affiliated with management $ 21,385 $ 268 $ 290 Purchases from entities affiliated with management $ 4,382 $ 3,870 $ 15,209 Sales to equity method investees $ — $ 294 $ 692 Purchases from equity method investees $ — $ 66,820 $ 121,336 (1) Amount primarily relates to purchases of crude oil under the definitive agreement we signed with WPX, as discussed further below.
Schedule of accounts receivable from affiliates	Accounts receivable from affiliates consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Receivables from NGL Energy Holdings LLC $ 7,277 $ 4,693 Receivables from WPX 5,185 — Receivables from SemGroup 71 49 Receivables from entities affiliated with management 334 24 Receivables from equity method investees — 6 Total $ 12,867 $ 4,772
Schedule of accounts payable to affiliates	Accounts payable to affiliates consist of the following at the dates indicated: March 31, 2019 2018 (in thousands) Payables to WPX $ 27,844 $ — Payables to entities affiliated with management 625 1,246 Payables to equity method investees — 8 Total $ 28,469 $ 1,254
Schedule of capital expenditures	The allocation of the consideration was as follows (in thousands): Current assets $ 276 Property, plant and equipment 1,366 Intangible assets (customer relationships) 4,782 Fair value of net assets acquired $ 6,424

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Mar. 31, 2019
Revenue from Contract with Customer [Abstract]
Schedule of impact of adoption of new accounting standard	The following tables summarize the impact of adoption on our consolidated balance sheet at March 31, 2019 and our consolidated statements of operations for the year ended March 31, 2019 : Consolidated Balance Sheet March 31, 2019 As Reported Balances Without Adoption of ASC 606 Effect of Change (in thousands) Accrued expenses and other liabilities $ 107,759 $ 137,872 $ (30,113 ) Other noncurrent liabilities $ 63,542 $ 142,623 $ (79,081 ) Equity: General partner $ (50,603 ) $ (50,712 ) $ 109 Limited partners $ 2,067,197 $ 1,958,113 $ 109,084 Consolidated Statement of Operations March 31, 2019 As Reported Balances Without Adoption of ASC 606 Effect of Change (in thousands) Loss on disposal or impairment of assets, net $ 34,296 $ 4,183 $ 30,113 Operating income $ 126,728 $ 156,841 $ (30,113 ) Net income $ 339,395 $ 369,508 $ (30,113 )
Schedule of amount and timing of remaining performance obligation	The following table summarizes the amount and timing of revenue recognition for such contracts at March 31, 2019 (in thousands): Fiscal Year Ending March 31, 2020 $ 167,061 2021 128,572 2022 119,016 2023 113,861 2024 99,430 Thereafter 242,032 Total $ 869,972
Schedule of contract assets and liabilities	The following tables summarizes the balances of our contract assets and liabilities at the dates indicated (in thousands): Balance at April 1, 2018 March 31, 2019 Accounts receivable from contracts with customers $ 542,593 $ 613,827 Contract liabilities balance at April 1, 2018 $ 7,889 Payment received and deferred 77,981 Payment recognized in revenue (77,409 ) Contract liabilities balance at March 31, 2019 $ 8,461 Amounts in the tables above do not include contract assets and liabilities related to TPSL, as these amounts have been classified as current assets and current liabilities held for sale within our March 31, 2019 consolidated balance sheet (see Note 1 and Note 17

Assets, Liabilities and Redee_2

Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations (Tables)	12 Months Ended
	Mar. 31, 2019
Discontinued Operations and Disposal Groups [Abstract]
Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations	The following table summarizes the major classes of assets, liabilities and redeemable noncontrolling interest classified as held for sale at the dates indicated: March 31, 2019 2018 (in thousands) Current Assets Held for Sale Cash and cash equivalents $ — $ 4,113 Accounts receivable-trade, net 164,716 252,136 Inventories 327,015 402,904 Prepaid expenses and other current assets 89,254 49,518 Total current assets held for sale 580,985 708,671 Noncurrent Assets Held for Sale Property, plant and equipment, net 15,553 207,661 Goodwill 35,405 142,028 Intangible assets, net 137,446 279,395 Other noncurrent assets (1) 46,147 42,987 Total noncurrent assets held for sale 234,551 672,071 Total assets held for sale $ 815,536 $ 1,380,742 Current Liabilities Held for Sale Accounts payable-trade $ 85,602 $ 79,432 Accrued expenses and other payables 140,691 92,845 Advance payments received from customers 460 13,327 Current maturities of long-term debt — 2,550 Total current liabilities held for sale 226,753 188,154 Noncurrent Liabilities Held for Sale Long-term debt, net — 2,888 Other noncurrent liabilities 33 190 Total noncurrent liabilities held for sale 33 3,078 Total liabilities held for sale 226,786 191,232 Redeemable Noncontrolling Interest Held for Sale Redeemable noncontrolling interest — 9,927 Total liabilities and redeemable noncontrolling interest held for sale $ 226,786 $ 201,159 (1) Primarily comprised of tank bottoms, which are product volumes required for the operation of storage tanks, that are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. At March 31, 2019 and 2018, tank bottoms held in third party terminals consisted of 389,737 barrels and 366,212 barrels of refined products, respectively. Tank bottoms held in terminals we own are included within property, plant and equipment (see Note 5). The following table summarizes the results of operations from discontinued operations for the periods indicated: Year Ended March 31, 2019 2018 2017 (in thousands) Revenues $ 15,398,608 $ 10,474,860 $ 7,904,143 Cost of sales 15,338,614 10,418,447 7,681,429 Operating expenses 37,348 137,780 134,879 General and administrative expense 2,716 11,471 15,727 Depreciation and amortization 9,593 44,314 43,592 Gain on disposal or impairment of assets, net (1) (407,608 ) (88,194 ) (196 ) Operating income (loss) from discontinued operations 417,945 (48,958 ) 28,712 Equity in earnings (loss) of unconsolidated entities 1,183 425 (746 ) Interest expense (126 ) (421 ) (877 ) Other income, net 837 1,930 1,244 Income (loss) from discontinued operations before taxes (2) 419,839 (47,024 ) 28,333 Income tax expense (989 ) (104 ) (6 ) Income (loss) from discontinued operations, net of tax $ 418,850 $ (47,128 ) $ 28,327 (1) Amount for the year ended March 31, 2019 includes a gain of $408.9 million on the sale of virtually all of our remaining Retail Propane segment to Superior on July 10, 2018, partially offset by a loss of $1.3 million on the sale of a portion of our Retail Propane segment to DCC on March 30, 2018 related to a working capital adjustment. (2) Amounts include income (loss) attributable to redeemable noncontrolling interests. Loss attributable to redeemable noncontrolling interest was $0.4 million for the year ended March 31, 2019 and income attributable to redeemable noncontrolling interest was $1.0 million for the year ended March 31, 2018 .

Quarterly Financial Data (Una_2

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Mar. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Schedule of summarized unaudited quarterly financial data	The following tables summarize our unaudited quarterly financial data. The computation of net income (loss) per common unit is done separately by quarter and year. The total of net income (loss) per common unit of the individual quarters may not equal net income (loss) per common unit for the year, due primarily to the income allocation between the general partner and limited partners and variations in the weighted average units outstanding used in computing such amounts. Our former Retail Propane segment’s business (included within discontinued operations, see Note 17 ) is seasonal due to weather conditions in our service areas. Its results are affected by winter heating season requirements, which generally results in net income during the period from October through March of each year and either net losses or lower net income during the period from April through September of each year. Our Liquids segment is also subject to seasonal fluctuations, as demand for propane and butane is typically higher during the winter months. Our operating revenues from our other segments are less weather sensitive. Additionally, the acquisitions described in Note 4 impact the comparability of the quarterly information within the year, and year to year. Quarter Ended Year Ended June 30, 2018 September 30, 2018 December 31, 2018 March 31, 2019 March 31, 2019 (in thousands, except unit and per unit amounts) Total revenues $ 2,054,952 $ 2,215,682 $ 2,295,369 $ 2,123,154 $ 8,689,157 Total cost of sales $ 1,946,565 $ 2,051,448 $ 2,048,659 $ 1,936,389 $ 7,983,061 (Loss) income from continuing operations $ (202,799 ) $ (31,725 ) $ 97,202 $ 57,867 $ (79,455 ) Net (loss) income $ (169,289 ) $ 354,939 $ 110,528 $ 43,217 $ 339,395 Net (loss) income attributable to NGL Energy Partners LP $ (168,546 ) $ 355,505 $ 110,835 $ 62,253 $ 360,047 Basic (loss) income per common unit (Loss) income from continuing operations $ (1.83 ) $ (0.45 ) $ 0.55 $ 0.31 $ (1.39 ) Net (loss) income $ (1.55 ) $ 2.70 $ 0.65 $ 0.20 $ 2.01 Diluted (loss) income per common unit (Loss) income from continuing operations $ (1.83 ) $ (0.45 ) $ 0.54 $ 0.31 $ (1.39 ) Net (loss) income $ (1.55 ) $ 2.70 $ 0.64 $ 0.19 $ 2.01 Basic weighted average common units outstanding 121,544,421 122,380,197 123,892,680 124,262,014 123,017,064 Diluted weighted average common units outstanding 121,544,421 122,380,197 125,959,751 126,926,589 123,017,064 Quarter Ended Year Ended June 30, 2017 September 30, 2017 December 31, 2017 March 31, 2018 March 31, 2018 (in thousands, except unit and per unit amounts) Total revenues $ 1,361,513 $ 1,452,072 $ 1,996,370 $ 2,143,992 $ 6,953,947 Total cost of sales $ 1,216,591 $ 1,279,871 $ 1,807,132 $ 1,959,967 $ 6,263,561 (Loss) income from continuing operations $ (13,004 ) $ (109,381 ) $ 105,035 $ (5,127 ) $ (22,477 ) Net (loss) income $ (63,707 ) $ (173,579 ) $ 56,769 $ 110,912 $ (69,605 ) Net (loss) income attributable to NGL Energy Partners LP $ (63,362 ) $ (173,371 ) $ 56,256 $ 109,602 $ (70,875 ) Basic (loss) income per common unit (Loss) income from continuing operations $ (0.19 ) $ (1.03 ) $ 0.73 $ (0.19 ) $ (0.68 ) Net (loss) income $ (0.61 ) $ (1.56 ) $ 0.33 $ 0.76 $ (1.08 ) Diluted (loss) income per common unit (Loss) income from continuing operations $ (0.19 ) $ (1.03 ) $ 0.71 $ (0.19 ) $ (0.68 ) Net (loss) income $ (0.61 ) $ (1.56 ) $ 0.32 $ 0.76 $ (1.08 ) Basic weighted average common units outstanding 120,535,909 121,314,636 120,844,008 121,271,959 120,991,340 Diluted weighted average common units outstanding 120,535,909 121,314,636 124,161,966 121,271,959 120,991,340

Consolidating Guarantor and N_2

Consolidating Guarantor and Non-Guarantor Financial Information (Tables)	12 Months Ended
	Mar. 31, 2019
Consolidating Guarantor and Non-Guarantor Financial Information [Abstract]
Schedule of Consolidating Balance Sheets	Consolidating Balance Sheet (in Thousands) March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 12,798 $ — $ 3,728 $ 2,046 $ — $ 18,572 Accounts receivable-trade, net of allowance for doubtful accounts — — 996,192 2,011 — 998,203 Accounts receivable-affiliates — — 12,867 — — 12,867 Inventories — — 135,094 1,034 — 136,128 Prepaid expenses and other current assets — — 65,443 475 — 65,918 Assets held for sale — — 580,985 — — 580,985 Total current assets 12,798 — 1,794,309 5,566 — 1,812,673 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,620,084 208,856 — 1,828,940 GOODWILL — — 1,105,281 5,175 — 1,110,456 INTANGIBLE ASSETS, net of accumulated amortization — — 725,542 75,347 — 800,889 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 1,127 — — 1,127 NET INTERCOMPANY RECEIVABLES (PAYABLES) 862,186 — (808,610 ) (53,576 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 2,503,848 — 170,690 — (2,674,538 ) — OTHER NONCURRENT ASSETS — — 113,857 — — 113,857 ASSETS HELD FOR SALE — — 234,551 — — 234,551 Total assets $ 3,378,832 $ — $ 4,956,831 $ 241,368 $ (2,674,538 ) $ 5,902,493 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 872,122 $ 6,941 $ — $ 879,063 Accounts payable-affiliates 1 — 28,468 — — 28,469 Accrued expenses and other payables 25,497 — 80,765 1,497 — 107,759 Advance payments received from customers — — 7,550 911 — 8,461 Current maturities of long-term debt — — 648 — — 648 Liabilities held for sale — — 226,753 — — 226,753 Total current liabilities 25,498 — 1,216,306 9,349 — 1,251,153 LONG-TERM DEBT, net of debt issuance costs and current maturities 984,450 — 1,175,683 — — 2,160,133 OTHER NONCURRENT LIABILITIES — — 60,961 2,581 — 63,542 NONCURRENT LIABILITIES HELD FOR SALE — — 33 — — 33 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 149,814 — — — — 149,814 EQUITY: Partners’ equity 2,219,070 — 2,503,848 229,693 (2,733,286 ) 2,219,325 Accumulated other comprehensive loss — — — (255 ) — (255 ) Noncontrolling interests — — — — 58,748 58,748 Total equity 2,219,070 — 2,503,848 229,438 (2,674,538 ) 2,277,818 Total liabilities and equity $ 3,378,832 $ — $ 4,956,831 $ 241,368 $ (2,674,538 ) $ 5,902,493 Consolidating Balance Sheet (in Thousands) March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 16,915 $ — $ 3,329 $ 1,850 $ — $ 22,094 Accounts receivable-trade, net of allowance for doubtful accounts — — 815,404 5,148 — 820,552 Accounts receivable-affiliates — — 4,772 — — 4,772 Inventories — — 161,324 325 — 161,649 Prepaid expenses and other current assets — — 81,589 431 — 82,020 Assets held for sale — — 681,867 26,804 — 708,671 Total current assets 16,915 — 1,748,285 34,558 — 1,799,758 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,365,174 147,112 — 1,512,286 GOODWILL — — 1,093,270 77,260 — 1,170,530 INTANGIBLE ASSETS, net of accumulated amortization — — 691,382 83,705 — 775,087 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 17,236 — — 17,236 NET INTERCOMPANY RECEIVABLES (PAYABLES) 2,110,940 — (2,121,741 ) 10,801 — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,703,327 — 244,109 — (1,947,436 ) — LOAN RECEIVABLE-AFFILIATE — — 1,200 — — 1,200 OTHER NONCURRENT ASSETS — — 202,954 — — 202,954 ASSETS HELD FOR SALE — — 672,071 — — 672,071 Total assets $ 3,831,182 $ — $ 3,913,940 $ 353,436 $ (1,947,436 ) $ 6,151,122 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 778,965 $ 2,232 $ — $ 781,197 Accounts payable-affiliates 1 — 1,253 — — 1,254 Accrued expenses and other payables 41,104 — 94,853 1,285 — 137,242 Advance payments received from customers — — 4,022 3,867 — 7,889 Current maturities of long-term debt — — 646 — — 646 Liabilities held for sale — — 175,640 12,514 — 188,154 Total current liabilities 41,105 — 1,055,379 19,898 — 1,116,382 LONG-TERM DEBT, net of debt issuance costs and current maturities 1,704,909 — 974,831 — — 2,679,740 OTHER NONCURRENT LIABILITIES — — 167,398 5,926 — 173,324 NONCURRENT LIABILITIES HELD FOR SALE — — 3,078 — — 3,078 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 82,576 — — — — 82,576 REDEEMABLE NONCONTROLLING INTEREST HELD FOR SALE — — 9,927 — — 9,927 EQUITY: Partners’ equity 2,002,592 — 1,704,896 327,858 (2,030,939 ) 2,004,407 Accumulated other comprehensive loss — — (1,569 ) (246 ) — (1,815 ) Noncontrolling interests — — — — 83,503 83,503 Total equity 2,002,592 — 1,703,327 327,612 (1,947,436 ) 2,086,095 Total liabilities and equity $ 3,831,182 $ — $ 3,913,940 $ 353,436 $ (1,947,436 ) $ 6,151,122
Schedule of Consolidating Statements of Operations	Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 8,665,597 $ 27,542 $ (3,982 ) $ 8,689,157 COST OF SALES — — 7,986,019 1,024 (3,982 ) 7,983,061 OPERATING COSTS AND EXPENSES: Operating — — 217,597 13,468 — 231,065 General and administrative — — 106,595 812 — 107,407 Depreciation and amortization — — 201,513 10,460 — 211,973 (Gain) loss on disposal or impairment of assets, net — — (31,924 ) 66,220 — 34,296 Revaluation of liabilities — — (5,373 ) — — (5,373 ) Operating Income (Loss) — — 191,170 (64,442 ) — 126,728 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 2,533 — — 2,533 Interest expense (104,716 ) — (60,008 ) (46 ) 45 (164,725 ) Loss on early extinguishment of liabilities, net (12,340 ) — — — — (12,340 ) Other expense, net — — (30,187 ) — (231 ) (30,418 ) (Loss) Income From Continuing Operations Before Income Taxes (117,056 ) — 103,508 (64,488 ) (186 ) (78,222 ) INCOME TAX EXPENSE — — (1,233 ) — — (1,233 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 477,103 — (44,865 ) — (432,238 ) — Income (Loss) From Continuing Operations 360,047 — 57,410 (64,488 ) (432,424 ) (79,455 ) Income (Loss) From Discontinued Operations, Net of Tax — — 419,693 (1,029 ) 186 418,850 Net Income (Loss) 360,047 — 477,103 (65,517 ) (432,238 ) 339,395 LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS 20,206 20,206 LESS: NET LOSS ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS 446 446 NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ 360,047 $ — $ 477,103 $ (65,517 ) $ (411,586 ) $ 360,047 Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 6,935,485 $ 19,954 $ (1,492 ) $ 6,953,947 COST OF SALES — — 6,263,562 1,491 (1,492 ) 6,263,561 OPERATING COSTS AND EXPENSES: Operating — — 186,056 7,020 — 193,076 General and administrative — — 97,402 577 — 97,979 Depreciation and amortization — — 197,497 10,901 — 208,398 (Gain) loss on disposal or impairment of assets, net — — (133,993 ) 116,875 — (17,118 ) Revaluation of liabilities — — 20,124 592 — 20,716 Operating Income (Loss) — — 304,837 (117,502 ) — 187,335 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 7,539 — — 7,539 Interest expense (142,159 ) — (56,989 ) (46 ) 45 (199,149 ) Loss on early extinguishment of liabilities, net (23,201 ) — — — — (23,201 ) Other income, net — — 7,152 19 (819 ) 6,352 (Loss) Income From Continuing Operations Before Income Taxes (165,360 ) — 262,539 (117,529 ) (774 ) (21,124 ) INCOME TAX EXPENSE — — (1,353 ) — — (1,353 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 94,485 — (116,224 ) — 21,739 — (Loss) Income From Continuing Operations (70,875 ) — 144,962 (117,529 ) 20,965 (22,477 ) (Loss) Income From Discontinued Operations, Net of Tax — — (50,477 ) 2,575 774 (47,128 ) Net (Loss) Income (70,875 ) — 94,485 (114,954 ) 21,739 (69,605 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (240 ) (240 ) LESS: NET INCOME ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS (1,030 ) (1,030 ) NET (LOSS) INCOME ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ (70,875 ) $ — $ 94,485 $ (114,954 ) $ 20,469 $ (70,875 ) Consolidating Statement of Operations (in Thousands) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 5,197,416 $ 19,639 $ (790 ) $ 5,216,265 COST OF SALES — — 4,738,820 533 (790 ) 4,738,563 OPERATING COSTS AND EXPENSES: Operating — — 166,519 6,527 — 173,046 General and administrative — — 100,436 403 — 100,839 Depreciation and amortization — — 172,172 7,441 — 179,613 Gain on disposal or impairment of assets, net — — (208,982 ) — — (208,982 ) Revaluation of liabilities — — 6,305 412 — 6,717 Operating Income — — 222,146 4,323 — 226,469 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 3,830 — — 3,830 Revaluation of investments — — (14,365 ) — — (14,365 ) Interest expense (91,259 ) — (58,214 ) (174 ) 46 (149,601 ) Gain on early extinguishment of liabilities, net 8,507 — 16,220 — — 24,727 Other income, net — — 27,013 — (593 ) 26,420 (Loss) Income From Continuing Operations Before Income Taxes (82,752 ) — 196,630 4,149 (547 ) 117,480 INCOME TAX EXPENSE — — (1,933 ) — — (1,933 ) EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES 219,794 — (1,336 ) — (218,458 ) — Income From Continuing Operations 137,042 — 193,361 4,149 (219,005 ) 115,547 Income From Discontinued Operations, Net of Tax — — 26,433 1,347 547 28,327 Net Income 137,042 — 219,794 5,496 (218,458 ) 143,874 LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (6,832 ) (6,832 ) NET INCOME ATTRIBUTABLE TO NGL ENERGY PARTNER LP $ 137,042 $ — $ 219,794 $ 5,496 $ (225,290 ) $ 137,042
Schedule of Consolidating Statements of Comprehensive Income (Loss)	Consolidating Statements of Comprehensive Income (Loss) (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income (loss) $ 360,047 $ — $ 477,103 $ (65,517 ) $ (432,238 ) $ 339,395 Other comprehensive (los s) income — — (18 ) 9 — (9 ) Comprehensive income (loss) $ 360,047 $ — $ 477,085 $ (65,508 ) $ (432,238 ) $ 339,386 Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (70,875 ) $ — $ 94,485 $ (114,954 ) $ 21,739 $ (69,605 ) Other comprehensive income (loss) — — 58 (45 ) — 13 Comprehensive (loss) income $ (70,875 ) $ — $ 94,543 $ (114,999 ) $ 21,739 $ (69,592 ) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income $ 137,042 $ — $ 219,794 $ 5,496 $ (218,458 ) $ 143,874 Other comprehensive loss — — (1,626 ) (45 ) — (1,671 ) Comprehensive income $ 137,042 $ — $ 218,168 $ 5,451 $ (218,458 ) $ 142,203
Schedule of Consolidating Statements of Cash Flows	Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2019 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (116,033 ) $ — $ 295,293 $ (27,551 ) $ (186 ) $ 151,523 Net cash provided by operating activities-discontinued operations — — 182,506 3,221 — 185,727 Net cash (used in) provided by operating activities (116,033 ) — 477,799 (24,330 ) (186 ) 337,250 INVESTING ACTIVITIES: Capital expenditures — — (414,522 ) (41,064 ) — (455,586 ) Acquisitions, net of cash acquired — — (296,687 ) (3,927 ) — (300,614 ) Net settlements of commodity derivatives — — (10,173 ) — — (10,173 ) Proceeds from sales of assets — — 16,177 — — 16,177 Proceeds from divestitures of businesses and investments, net — — 335,809 — — 335,809 Investments in unconsolidated entities — — (389 ) — — (389 ) Distributions of capital from unconsolidated entities — — 1,440 — — 1,440 Repayments on loan for natural gas liquids facility — — 10,336 — — 10,336 Loan to affiliate — — (1,515 ) — — (1,515 ) Net cash used in investing activities-continuing operations — — (359,524 ) (44,991 ) — (404,515 ) Net cash provided by investing activities-discontinued operations — — 851,006 6,982 — 857,988 Net cash provided by (used in) investing activities — — 491,482 (38,009 ) — 453,473 FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 4,098,500 — — 4,098,500 Payments on revolving credit facilities — — (3,897,000 ) — — (3,897,000 ) Repayment and repurchase of senior secured and senior unsecured notes (737,058 ) — — — — (737,058 ) Payments on other long-term debt — — (653 ) — — (653 ) Debt issuance costs (30 ) — (1,353 ) — — (1,383 ) Contributions from noncontrolling interest owners, net — — — 169 — 169 Distributions to general and common unit partners and preferred unitholders (236,633 ) — — — — (236,633 ) Repurchase of warrants (14,988 ) — — — — (14,988 ) Common unit repurchases and cancellations (297 ) — — — — (297 ) Payments for settlement and early extinguishment of liabilities — — (4,577 ) — — (4,577 ) Net changes in advances with consolidated entities 1,100,922 — (1,163,504 ) 62,396 186 — Net cash provided by (used in) financing activities-continuing operations 111,916 — (968,587 ) 62,565 186 (793,920 ) Net cash used in financing activities-discontinued operations — — (295 ) (30 ) — (325 ) Net cash provided by (used in) financing activities 111,916 — (968,882 ) 62,535 186 (794,245 ) Net (decrease) increase in cash and cash equivalents (4,117 ) — 399 196 — (3,522 ) Cash and cash equivalents, beginning of period 16,915 — 3,329 1,850 — 22,094 Cash and cash equivalents, end of period $ 12,798 $ — $ 3,728 $ 2,046 $ — $ 18,572 Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2018 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (141,967 ) $ — $ 433,678 $ 9,411 $ (774 ) $ 300,348 Net cash (used in) provided by operating activities-discontinued operations — — (165,862 ) 3,481 — (162,381 ) Net cash (used in) provided by operating activities (141,967 ) — 267,816 12,892 (774 ) 137,967 INVESTING ACTIVITIES: Capital expenditures — — (130,760 ) (3,001 ) — (133,761 ) Acquisitions, net of cash acquired — — 3,100 (22,997 ) — (19,897 ) Net settlements of commodity derivatives — — (39,113 ) — — (39,113 ) Proceeds from sales of assets — — 33,844 — — 33,844 Proceeds from divestitures of businesses and investments, net — — 292,112 37,668 — 329,780 Transaction with Victory Propane (Note 13) — — (6,424 ) — — (6,424 ) Investments in unconsolidated entities — — (21,465 ) — — (21,465 ) Distributions of capital from unconsolidated entities — — 11,969 — — 11,969 Repayments on loan for natural gas liquids facility — — 10,052 — — 10,052 Loan to affiliate — — (2,510 ) — — (2,510 ) Repayments on loan to affiliate — — 4,160 — — 4,160 Net cash provided by investing activities-continuing operations — — 154,965 11,670 — 166,635 Net cash provided by (used in) investing activities-discontinued operations — — 104,666 (719 ) — 103,947 Net cash provided by investing activities — — 259,631 10,951 — 270,582 FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 2,434,500 — — 2,434,500 Payments on revolving credit facilities — — (2,279,500 ) — — (2,279,500 ) Repayment and repurchase of senior secured and senior unsecured notes (486,699 ) — — — — (486,699 ) Payments on other long-term debt — — (877 ) — — (877 ) Debt issuance costs (692 ) — (2,008 ) — — (2,700 ) Contributions from noncontrolling interest owners, net — — — 23 — 23 Distributions to general and common unit partners and preferred unitholders (225,067 ) — — — — (225,067 ) Distributions to noncontrolling interest owners — — — (3,082 ) — (3,082 ) Proceeds from sale of preferred units, net of offering costs 202,731 — — — — 202,731 Repurchase of warrants (10,549 ) — — — — (10,549 ) Common unit repurchases and cancellations (15,817 ) — — — — (15,817 ) Payments for settlement and early extinguishment of liabilities — — (3,408 ) — — (3,408 ) Net changes in advances with consolidated entities 688,718 — (669,452 ) (20,040 ) 774 — Net cash provided by (used in) financing activities-continuing operations 152,625 — (520,745 ) (23,099 ) 774 (390,445 ) Net cash used in financing activities-discontinued operations — — (3,446 ) (390 ) — (3,836 ) Net cash provided by (used in) financing activities 152,625 — (524,191 ) (23,489 ) 774 (394,281 ) Net increase in cash and cash equivalents 10,658 — 3,256 354 — 14,268 Cash and cash equivalents, beginning of period 6,257 — 73 1,496 — 7,826 Cash and cash equivalents, end of period $ 16,915 $ — $ 3,329 $ 1,850 $ — $ 22,094 Consolidating Statement of Cash Flows (in Thousands) Year Ended March 31, 2017 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Adjustments Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities-continuing operations $ (749,250 ) $ — $ 750,978 $ 16,675 $ (547 ) $ 17,856 Net cash (used in) provided by operating activities-discontinued operations — — (47,923 ) 5,029 — (42,894 ) Net cash (used in) provided by operating activities (749,250 ) — 703,055 21,704 (547 ) (25,038 ) INVESTING ACTIVITIES: Capital expenditures — — (296,395 ) (6,367 ) — (302,762 ) Acquisitions, net of cash acquired — — (41,928 ) — — (41,928 ) Net settlements of commodity derivatives — — 9,648 — — 9,648 Proceeds from sales of assets — — 28,232 — — 28,232 Proceeds from divestitures of businesses and investments, net — — 112,370 22,000 — 134,370 Investments in unconsolidated entities — — (2,105 ) — — (2,105 ) Distributions of capital from unconsolidated entities — — 9,692 — — 9,692 Repayments on loan for natural gas liquids facility — — 8,916 — — 8,916 Loan to affiliate — — (3,200 ) — — (3,200 ) Repayments on loan to affiliate — — 655 — — 655 Payment to terminate development agreement — — (16,875 ) — — (16,875 ) Net cash (used in) provided by investing activities-continuing operations — — (190,990 ) 15,633 — (175,357 ) Net cash used in investing activities-discontinued operations — — (175,371 ) (12,398 ) — (187,769 ) Net cash (used in) provided by investing activities — — (366,361 ) 3,235 — (363,126 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 1,700,000 — — 1,700,000 Payments on revolving credit facilities — — (2,733,500 ) — — (2,733,500 ) Issuance of senior unsecured notes 1,200,000 — — — — 1,200,000 Repayment and repurchase of senior secured and senior unsecured notes (21,193 ) — — — — (21,193 ) Payments on other long-term debt — — (46,153 ) — — (46,153 ) Debt issuance costs (21,868 ) — (11,690 ) — — (33,558 ) Contributions from general partner 49 — — — — 49 Contributions from noncontrolling interest owners, net — — — 672 — 672 Distributions to general and common unit partners and preferred unitholders (181,581 ) — — — — (181,581 ) Distributions to noncontrolling interest owners — — — (3,292 ) — (3,292 ) Proceeds from sale of preferred units, net of offering costs 234,975 — — — — 234,975 Proceeds from sale of common units, net of offering costs 287,136 — — — — 287,136 Payments for settlement and early extinguishment of liabilities — — (28,468 ) — — (28,468 ) Net changes in advances with consolidated entities (767,760 ) — 788,334 (21,121 ) 547 — Net cash provided by (used in) financing activities-continuing operations 729,758 — (331,477 ) (23,741 ) 547 375,087 Net cash used in financing activities-discontinued operations — — (3,443 ) (190 ) — (3,633 ) Net cash provided by (used in) financing activities 729,758 — (334,920 ) (23,931 ) 547 371,454 Net (decrease) increase in cash and cash equivalents (19,492 ) — 1,774 1,008 — (16,710 ) Cash and cash equivalents, beginning of period 25,749 — (1,701 ) 488 — 24,536 Cash and cash equivalents, end of period $ 6,257 $ — $ 73 $ 1,496 $ — $ 7,826

Nature of Operations and Orga_2

Nature of Operations and Organization (Details) $ in Thousands	Sep. 30, 2019USD ($)terminal	Jul. 10, 2018USD ($)	Mar. 31, 2019USD ($)terminal	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)	Jun. 30, 2018
Nature of Operations and Organization
Proceeds from divestitures of businesses and investments, net | $			$ 335,809	$ 329,780	$ 134,370
Ownership interest			0.00%			50.00%
Liquids
Nature of Operations and Organization
Number of owned terminals | terminal			27
TransMontaigne Product Services, LLC | Refined products and renewables
Nature of Operations and Organization
Number of owned terminals | terminal	2
Proceeds from divestitures of businesses and investments, net | $	$ 233,800
Number of terminals to be utilized | terminal	19
Retail Propane Segment - East
Nature of Operations and Organization
Proceeds from divestitures of businesses and investments, net | $		$ 889,800

Significant Accounting Polici_4

Significant Accounting Policies - Income Taxes (Details) $ in Millions	12 Months Ended
	Mar. 31, 2019USD ($)
Minimum percentage of qualifying income of non-taxable subsidiaries	90.00%
Noncurrent deferred tax liability at balance sheet date	$ 14.8
Ranch | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Initial noncurrent deferred tax liability	16.3
Deferred income tax benefit	$ 1.5
Effective income tax rate	31.00%

Significant Accounting Polici_5

Significant Accounting Policies - Accounts Receivable and Concentration of Credit Risk (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Mar. 31, 2019	Mar. 31, 2018
Accounts receivable
Gross Receivable				$ 1,002,219	$ 824,403
Allowance for Doubtful Accounts	$ (3,851)	$ (3,604)	$ (3,604)	(4,016)	(3,851)
Accounts receivable - trade, net of allowance for doubtful accounts				998,203	820,552
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	(3,851)	(3,604)	(5,340)
Provision for doubtful accounts	(381)	(584)	739
Write off of uncollectible accounts	216	337	997
Allowance for doubtful accounts, end of period	(4,016)	(3,851)	$ (3,604)
Crude oil logistics
Accounts receivable
Gross Receivable				514,243	404,865
Allowance for Doubtful Accounts	0	0		(15)	0
Accounts receivable - trade, net of allowance for doubtful accounts				514,228	404,865
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	0
Allowance for doubtful accounts, end of period	(15)	0
Water solutions
Accounts receivable
Gross Receivable				57,526	59,958
Allowance for Doubtful Accounts	(2,952)	(2,952)		(3,157)	(2,952)
Accounts receivable - trade, net of allowance for doubtful accounts				54,369	57,006
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	(2,952)
Allowance for doubtful accounts, end of period	(3,157)	(2,952)
Liquids
Accounts receivable
Gross Receivable				134,050	131,006
Allowance for Doubtful Accounts	(20)	(20)		(177)	(20)
Accounts receivable - trade, net of allowance for doubtful accounts				133,873	130,986
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	(20)
Allowance for doubtful accounts, end of period	(177)	(20)
Refined products and renewables
Accounts receivable
Gross Receivable				295,984	228,574
Allowance for Doubtful Accounts	(879)	(879)		(667)	(879)
Accounts receivable - trade, net of allowance for doubtful accounts				295,317	227,695
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	(879)
Allowance for doubtful accounts, end of period	(667)	(879)
Corporate and Other
Accounts receivable
Gross Receivable				416	0
Allowance for Doubtful Accounts	0	0		0	0
Accounts receivable - trade, net of allowance for doubtful accounts				$ 416	$ 0
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period	0
Allowance for doubtful accounts, end of period	$ 0	$ 0

Significant Accounting Polici_6

Significant Accounting Policies - Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Mar. 31, 2018
Inventories
Crude oil	$ 51,359	$ 77,351
Natural gas liquids:
Propane	33,478	38,910
Butane	15,294	12,613
Other	7,482	6,515
Refined products and renewables:
Diesel	9,186	12,752
Ethanol	14,650	5,542
Biodiesel	4,679	7,966
Total	$ 136,128	$ 161,649

Significant Accounting Polici_7

Significant Accounting Policies - Investments in Unconsolidated Entities (Details) - USD ($) $ in Thousands	May 03, 2018	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Mar. 01, 2019	Aug. 14, 2018	Jun. 30, 2018
Investments in Unconsolidated Entities
Ownership interest		0.00%					50.00%
Carrying value		$ 1,127	$ 17,236			$ 800
Balance sheets:
Current assets		1,328	24,431
Noncurrent assets		519	99,164
Current liabilities		178	16,787
Noncurrent liabilities		0	10,620
Statements of operations:
Revenues		21,036	182,820	$ 180,632
Cost of sales		9,919	114,890	114,316
Net income		5,506	26,438	$ 19,462
Cumulative earnings and distributions from unconsolidated entities
Cumulative earnings from unconsolidated entities		1,900
Cumulative distributions received from unconsolidated entities		$ 3,000
Water services company | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest		50.00%
Carrying value		$ 920	0
Natural gas liquids terminal company | Liquids | Operating segment
Investments in Unconsolidated Entities
Carrying value		$ 207	0
Water treatment and disposal facility | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest		0.00%
Carrying value		$ 0	$ 2,094
E Energy Adams, LLC | Refined products and renewables | Operating segment
Investments in Unconsolidated Entities
Ownership interest		0.00%	20.00%
Carrying value		$ 0	$ 15,142
Proceeds from sale of interest in equity method investee	$ 18,600
Gain on sale of interest in equity method investee		$ 3,000
Liquids Facilities 2019 Acquisitions Acquisition Accounting In Process | Natural gas liquids terminal company | Liquids | Operating segment
Investments in Unconsolidated Entities
Ownership interest					50.00%

Significant Accounting Polici_8

Significant Accounting Policies - Variable Interest Entity (Details) $ in Millions	Mar. 31, 2019USD ($)
Equity method investees | Loan agreement
Variable Interest Entity
Maximum borrowing capacity	$ 5

Significant Accounting Polici_9

Significant Accounting Policies - Other Noncurrent Assets (Details) $ in Thousands	3 Months Ended	12 Months Ended
	Jun. 30, 2018USD ($)	Mar. 31, 2019USD ($)bbl	Mar. 31, 2018USD ($)bbl
Other Assets, Noncurrent [Abstract]
Loan receivable		$ 19,474	$ 29,463
Line fill		33,437	34,897
Minimum shipping fees - pipeline commitments		23,494	88,757
Other		37,452	49,837
Total		$ 113,857	$ 202,954
Crude oil
Number of barrels of product | bbl		335,069	360,425
Propane sales
Number of barrels of product | bbl		262,000	262,000
Customer contracts | Contract No. 1
Pipeline commitments, period to recover amount		13 months
Crude oil logistics
Number of contracts		2
Number of contracts with benefit of deficiency credits	1
Write-off of pipeline deficiency credits	$ 67,700

Significant Accounting Polic_10

Significant Accounting Policies - Accrued Expenses and Other Payables (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Mar. 31, 2018
Accounting Policies [Abstract]
Accrued compensation and benefits	$ 19,312	$ 17,778
Excise and other tax liabilities	10,481	8,279
Derivative liabilities	4,960	8,321
Accrued interest	24,882	39,947
Product exchange liabilities	5,945	1,116
Gavilon legal matter settlement (Note 9)	12,500	0
Deferred gain on sale of general partner interest in TLP (1)	0	30,113
Other	29,679	31,688
Total	$ 107,759	$ 137,242

Significant Accounting Polic_11

Significant Accounting Policies - Noncontrolling Interests (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Redeemable Noncontrolling Interest [Roll Forward]
Balance at beginning of period	$ 9,927
Net income attributable to redeemable noncontrolling interest	446	$ (1,030)	$ 0
Redeemable noncontrolling interest valuation adjustment	(3,349)	(5,825)
Balance at end of period	0	9,927
Redeemable noncontrolling interest
Redeemable Noncontrolling Interest [Roll Forward]
Balance at beginning of period	9,927	3,072
Net income attributable to redeemable noncontrolling interest	(446)	1,030
Redeemable noncontrolling interest valuation adjustment	3,349	5,825
Disposal of redeemable noncontrolling interest	(12,830)
Balance at end of period	$ 0	$ 9,927	$ 3,072

Significant Accounting Polic_12

Significant Accounting Policies - Recent Accounting Pronouncements (Details) $ in Thousands	Mar. 31, 2019USD ($)
Cumulative effect adjustment for adoption of ASU 2016-01 (Note 2)	$ 0
Limited Partner | Accumulated other comprehensive income (loss)
Cumulative effect adjustment for adoption of ASU 2016-01 (Note 2)	1,569
Minimum
Right of use assets and lease liabilities	533,000
Maximum
Right of use assets and lease liabilities	$ 563,000

Income (Loss) Per Common Unit_2

Income (Loss) Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Income (Loss) Per Common Unit
(Loss) income from continuing operations	$ 57,867	$ 97,202	$ (31,725)	$ (202,799)	$ (5,127)	$ 105,035	$ (109,381)	$ (13,004)	$ (79,455)	$ (22,477)	$ 115,547
Less: Continuing operations loss (income) attributable to noncontrolling interests									20,206	(240)	(6,832)
Net (loss) income from continuing operations attributable to NGL Energy Partners LP									(59,249)	(22,717)	108,715
Less: Distributions to preferred unitholders (1)									(111,936)	(59,697)	(30,142)
Less: Continuing operations net loss (income) allocated to general partner (2)									32	(53)	(204)
Less: Repurchase of warrants (3)									0	(349)	0
NET (LOSS) INCOME FROM CONTINUING OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)									(171,153)	(82,816)	78,369
Income (loss) from discontinued operations, net of tax									418,850	(47,128)	28,327
LESS: NET LOSS (INCOME) ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS									446	(1,030)	0
Less: Discontinued operations (income) loss allocated to general partner (2)									(419)	48	(28)
NET INCOME (LOSS) FROM DISCONTINUED OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)									418,877	(48,110)	28,299
NET INCOME (LOSS) ALLOCATED TO COMMON UNITHOLDERS									$ 247,724	$ (130,926)	$ 106,668
BASIC INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations	$ 0.31	$ 0.55	$ (0.45)	$ (1.83)	$ (0.19)	$ 0.73	$ (1.03)	$ (0.19)	$ (1.39)	$ (0.68)	$ 0.73
Income (loss) from discontinued operations, net of tax									3.41	(0.40)	0.26
Net Income (Loss)	0.20	0.65	2.70	(1.55)	0.76	0.33	(1.56)	(0.61)	2.01	(1.08)	0.99
DILUTED INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations	0.31	0.54	(0.45)	(1.83)	(0.19)	0.71	(1.03)	(0.19)	(1.39)	(0.68)	0.70
Income (loss) from discontinued operations, net of tax									3.41	(0.40)	0.25
Net Income (Loss)	$ 0.19	$ 0.64	$ 2.70	$ (1.55)	$ 0.76	$ 0.32	$ (1.56)	$ (0.61)	$ 2.01	$ (1.08)	$ 0.95
Basic weighted average common units outstanding (in units)	124,262,014	123,892,680	122,380,197	121,544,421	121,271,959	120,844,008	121,314,636	120,535,909	123,017,064	120,991,340	108,091,486
Diluted weighted average common units outstanding (in units)	126,926,589	125,959,751	122,380,197	121,544,421	121,271,959	124,161,966	121,314,636	120,535,909	123,017,064	120,991,340	111,850,621
Common units
BASIC INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations									$ (1.39)	$ (0.68)	$ 0.73
Income (loss) from discontinued operations, net of tax									3.41	(0.40)	0.26
Net Income (Loss)									2.01	(1.08)	0.99
DILUTED INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations									(1.39)	(0.68)	0.70
Income (loss) from discontinued operations, net of tax									3.41	(0.40)	0.25
Net Income (Loss)									$ 2.01	$ (1.08)	$ 0.95
Basic weighted average common units outstanding (in units)									123,017,064	120,991,340	108,091,486
Diluted weighted average common units outstanding (in units)									123,017,064	120,991,340	111,850,621
Common units | Performance awards
DILUTED INCOME (LOSS) PER COMMON UNIT
Weighted average number diluted shares outstanding adjustment									0	0	173,087
Common units | Warrant
DILUTED INCOME (LOSS) PER COMMON UNIT
Weighted average number diluted shares outstanding adjustment									0	0	3,586,048

Acquisitions - Water Pipeline C

Acquisitions - Water Pipeline Company (Details) - USD ($) $ in Thousands	May 14, 2019	Apr. 10, 2019	Apr. 03, 2019	Apr. 24, 2018	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Business Acquisition
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Carrying value of noncontrolling interest					$ 3,960	$ 22,883	$ 12,817
Water Pipeline Company
Business Acquisition
Ownership interest acquired				18.375%
Total consideration to acquire businesses				$ 4,000
Carrying value of noncontrolling interest				$ 3,900

Acquisitions - Saltwater Water

Acquisitions - Saltwater Water Solutions Facilities (Details) $ in Thousands	May 14, 2019USD ($)facility	Apr. 10, 2019USD ($)facility	Apr. 03, 2019USD ($)facility	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2019USD ($)facility	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Business Acquisition
Number of saltwater facilities acquired | facility		1
Number of saltwater wells acquired | facility	35	3	2
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Fair Value of Assets Acquired and Liabilities Assumed
Goodwill				$ 1,110,456				$ 1,170,530				$ 1,110,456	$ 1,170,530	$ 1,287,212
Revenues				2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	8,689,157	6,953,947	5,216,265
Operating income												$ 126,728	$ 187,335	$ 226,469
Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Number of saltwater facilities acquired | facility												6
Number of saltwater wells acquired | facility												15
Saltwater Facility | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Total consideration to acquire businesses												$ 116,100
Saltwater Facility | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Fair Value of Assets Acquired and Liabilities Assumed
Property, plant and equipment				36,590								36,590
Goodwill				50,619								50,619
Intangible assets				29,287								29,287
Current liabilities				(10)								(10)
Other noncurrent liabilities				(410)								(410)
Fair value of net assets acquired				$ 116,076								116,076
Revenues												12,600
Operating income												4,900
General and administrative expense												$ 200
Saltwater Facility
Fair Value of Assets Acquired and Liabilities Assumed
Number of wells acquired | facility												7
Payments to acquire assets												$ 35,200

Acquisitions - Freshwater Water

Acquisitions - Freshwater Water Disposal Facilities (Details) $ in Thousands	May 14, 2019USD ($)	Apr. 10, 2019USD ($)	Apr. 03, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2019USD ($)facility	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Business Acquisition
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Fair Value of Assets Acquired and Liabilities Assumed
Goodwill				$ 1,110,456				$ 1,170,530				$ 1,110,456	$ 1,170,530	$ 1,287,212
Revenues				2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	8,689,157	6,953,947	5,216,265
Operating income												$ 126,728	$ 187,335	$ 226,469
Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Number of freshwater facilities acquired | facility												4
Number of freshwater wells acquired | facility												27
Freshwater Facility | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Total consideration to acquire businesses												$ 77,200
Contingent consideration liability				2,700								2,700
Unfavorable lease liability				500								500
Ranch | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Initial noncurrent deferred tax liability				16,300								16,300
Freshwater Facility | Water Solutions Facilities 2019 Acquisitions Acquisition Accounting In Process
Fair Value of Assets Acquired and Liabilities Assumed
Property, plant and equipment				7,123								7,123
Goodwill				23,570								23,570
Intangible assets				64,015								64,015
Investments in unconsolidated entities				2,060								2,060
Current liabilities				(276)								(276)
Other noncurrent liabilities				(19,288)								(19,288)
Fair value of net assets acquired				$ 77,204								77,204
Revenues												2,000
Operating income												(1,100)
General and administrative expense												$ 3,700
Ranch
Business Acquisition
Number of freshwater wells acquired | facility												18
Fair Value of Assets Acquired and Liabilities Assumed
Payments to acquire assets												$ 28,400

Acquisitions - Natural Gas Liqu

Acquisitions - Natural Gas Liquids Terminal Business (Details) $ in Thousands	May 14, 2019USD ($)	Apr. 10, 2019USD ($)	Apr. 03, 2019USD ($)	Mar. 01, 2019USD ($)facility	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Business Acquisition
Ownership interest					0.00%			50.00%					0.00%
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Fair Value of Assets Acquired and Liabilities Assumed
Goodwill					$ 1,110,456				$ 1,170,530				$ 1,110,456	$ 1,170,530	$ 1,287,212
Revenues					2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	8,689,157	6,953,947	5,216,265
Operating income													126,728	187,335	226,469
Liquids Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Number of terminals acquired | facility				5
Total consideration to acquire businesses				$ 103,400
Fair Value of Assets Acquired and Liabilities Assumed
Inventories					15,370								15,370
Other current assets					667								667
Property, plant and equipment					42,413								42,413
Goodwill					20,472								20,472
Intangible assets					26,900								26,900
Investments in unconsolidated entities					204								204
Current liabilities					(2,128)								(2,128)
Other noncurrent liabilities					(524)								(524)
Fair value of net assets acquired					103,374								103,374
Revenues													22,700
Operating income													2,400
General and administrative expense													500
Liquids
Fair Value of Assets Acquired and Liabilities Assumed
Goodwill					$ 103,421				$ 149,169				103,421	149,169	266,046
Operating segment | Liquids
Fair Value of Assets Acquired and Liabilities Assumed
Revenues													2,415,041	2,215,985	1,537,172
Operating income													$ (2,910)	$ (93,113)	$ 43,252
Natural gas liquids terminal company | Operating segment | Liquids | Liquids Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Ownership interest				50.00%

Acquisitions - Refined Products

Acquisitions - Refined Products Terminals (Details) $ in Thousands	May 14, 2019USD ($)	Apr. 10, 2019USD ($)	Apr. 03, 2019USD ($)	Jan. 31, 2019USD ($)facility	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Business Acquisition
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Fair Value of Assets Acquired and Liabilities Assumed
Goodwill					$ 1,110,456				$ 1,170,530				$ 1,110,456	$ 1,170,530	$ 1,287,212
Revenues					2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	8,689,157	6,953,947	5,216,265
Operating income													126,728	$ 187,335	$ 226,469
Refined Products Facilities 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Number of terminals acquired | facility				2
Total consideration to acquire businesses				$ 16,300
Fair Value of Assets Acquired and Liabilities Assumed
Inventories					327								327
Other current assets					85								85
Property, plant and equipment					9,986								9,986
Goodwill					1,328								1,328
Intangible assets					4,600								4,600
Current liabilities					(4)								(4)
Fair value of net assets acquired					$ 16,322								16,322
Revenues													300
Operating income													(100)
General and administrative expense													$ 100

Acquisitions - Retail Propane B

Acquisitions - Retail Propane Businesses (Details) $ in Thousands	May 14, 2019USD ($)	Apr. 10, 2019USD ($)	Apr. 03, 2019USD ($)	Jul. 10, 2018facility	Jun. 30, 2018USD ($)facility	Mar. 31, 2019USD ($)	Jul. 09, 2018
Business Acquisition
Total consideration to acquire businesses	$ 892,500	$ 53,000	$ 13,000
Retail Propane Business 2019 Acquisitions Acquisition Accounting In Process
Business Acquisition
Total consideration to acquire businesses					$ 19,100
Number of businesses sold | facility					3
Retail Propane Company
Business Acquisition
Ownership interest acquired							40.00%
Retail Propane Business 2018 Acquisitions Acquisition Accounting In Process
Business Acquisition
Number of businesses sold | facility				4
Redeemable noncontrolling interest
Business Acquisition
Total consideration to acquire remaining interest						$ 12,830
Redeemable noncontrolling interest | Retail Propane Company
Business Acquisition
Total consideration to acquire remaining interest						$ 12,800

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Property, Plant and Equipment
Gross property, plant and equipment	$ 2,246,397	$ 1,853,508
Accumulated depreciation	(417,457)	(341,222)
Net property, plant and equipment	1,828,940	1,512,286
Depreciation expense	101,515	99,954	$ 89,848
Capitalized interest expense	482	182	6,887
(Gain) loss on sales and write-downs of certain assets	7,549	5,620	15,384
Crude oil logistics
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	3,489	(3,144)	8,124
Water solutions
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	3,067	8,117	7,169
Liquids
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	993	639	92
Corporate and Other
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	0	8	$ (1)
Natural gas liquids terminal and storage assets
Property, Plant and Equipment
Gross property, plant and equipment	$ 280,106	238,487
Natural gas liquids terminal and storage assets | Minimum
Property, Plant and Equipment
Useful life	2 years
Natural gas liquids terminal and storage assets | Maximum
Property, Plant and Equipment
Useful life	30 years
Pipeline and related facilities
Property, Plant and Equipment
Gross property, plant and equipment	$ 243,799	243,616
Pipeline and related facilities | Minimum
Property, Plant and Equipment
Useful life	30 years
Pipeline and related facilities | Maximum
Property, Plant and Equipment
Useful life	40 years
Vehicles and railcars
Property, Plant and Equipment
Gross property, plant and equipment	$ 124,948	121,159
Vehicles and railcars | Minimum
Property, Plant and Equipment
Useful life	3 years
Vehicles and railcars | Maximum
Property, Plant and Equipment
Useful life	25 years
Water treatment facilities and equipment
Property, Plant and Equipment
Gross property, plant and equipment	$ 704,666	601,139
Water treatment facilities and equipment | Minimum
Property, Plant and Equipment
Useful life	3 years
Water treatment facilities and equipment | Maximum
Property, Plant and Equipment
Useful life	30 years
Crude oil tanks and related equipment
Property, Plant and Equipment
Gross property, plant and equipment	$ 225,476	218,588
Crude oil tanks and related equipment | Minimum
Property, Plant and Equipment
Useful life	2 years
Crude oil tanks and related equipment | Maximum
Property, Plant and Equipment
Useful life	30 years
Barges and towboats
Property, Plant and Equipment
Gross property, plant and equipment	$ 103,735	92,712
Barges and towboats | Minimum
Property, Plant and Equipment
Useful life	5 years
Barges and towboats | Maximum
Property, Plant and Equipment
Useful life	30 years
Information technology equipment
Property, Plant and Equipment
Gross property, plant and equipment	$ 31,831	29,521
Information technology equipment | Minimum
Property, Plant and Equipment
Useful life	3 years
Information technology equipment | Maximum
Property, Plant and Equipment
Useful life	7 years
Buildings and leasehold improvements
Property, Plant and Equipment
Gross property, plant and equipment	$ 143,711	147,110
Buildings and leasehold improvements | Minimum
Property, Plant and Equipment
Useful life	3 years
Buildings and leasehold improvements | Maximum
Property, Plant and Equipment
Useful life	40 years
Land
Property, Plant and Equipment
Gross property, plant and equipment	$ 62,379	51,816
Tank bottoms and line fill
Property, Plant and Equipment
Gross property, plant and equipment	20,071	20,118
Other
Property, Plant and Equipment
Gross property, plant and equipment	$ 14,870	11,646
Other | Minimum
Property, Plant and Equipment
Useful life	3 years
Other | Maximum
Property, Plant and Equipment
Useful life	20 years
Construction in progress
Property, Plant and Equipment
Gross property, plant and equipment	$ 290,805	$ 77,596

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Sep. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2016
Goodwill [Roll Forward]
Goodwill at the beginning of the period			$ 1,170,530	$ 1,287,212
Revisions to acquisition accounting (Note 4)				195
Impairment			(66,220)	(116,877)
Acquisitions (Note 4)			94,661
Disposals (Note 16)			(88,515)
Goodwill at the end of the period	$ 1,110,456		1,110,456	1,170,530
Crude oil logistics
Goodwill [Roll Forward]
Goodwill at the beginning of the period			579,846	579,846
Goodwill at the end of the period	579,846		579,846	579,846
Water solutions
Goodwill [Roll Forward]
Goodwill at the beginning of the period			424,465	424,270
Revisions to acquisition accounting (Note 4)				195
Impairment					$ (380,200)
Acquisitions (Note 4)			74,189
Disposals (Note 16)			(88,515)
Goodwill at the end of the period	410,139		410,139	424,465
Liquids
Goodwill [Roll Forward]
Goodwill at the beginning of the period			149,169	266,046
Impairment	(66,200)	$ (116,900)	(66,220)	(116,877)
Acquisitions (Note 4)			20,472
Goodwill at the end of the period	103,421		103,421	149,169
Refined products and renewables
Goodwill [Roll Forward]
Goodwill at the beginning of the period			17,050	17,050
Acquisitions (Note 4)			0
Goodwill at the end of the period	$ 17,050		$ 17,050	$ 17,050

Goodwill Impairment (Details)

Goodwill Impairment (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Sep. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Mar. 31, 2016	Jan. 01, 2019	Mar. 30, 2018
Goodwill
Impairment			$ 66,220	$ 116,877
Goodwill	$ 1,110,456		1,110,456	1,170,530	$ 1,287,212
Liquids
Goodwill
Impairment	66,200	$ 116,900	66,220	116,877
Goodwill	103,421		103,421	149,169	266,046
Water solutions
Goodwill
Impairment						$ 380,200
Goodwill	$ 410,139		$ 410,139	$ 424,465	424,270
Adjustment to initial impairment estimate					$ 124,700
Sawtooth
Goodwill
Goodwill, impairment test, assumed per year increase in commodity prices		2.00%
Goodwill, impairment test, assumed per year increase in rental fees		4.00%					7.00%
Goodwill, impairment test, discount rate		12.00%					13.10%	12.40%
Reporting unit, percentage of fair value below carrying amount		32.00%					35.20%
Goodwill		$ 66,200
Reporting unit, percentage of fair value in excess of carrying amount								2.00%

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Thousands	Jun. 03, 2016	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Amortizable
Finite-lived intangible assets, gross		$ 1,301,206	$ 1,189,934
Accumulated amortization		(503,117)	(417,647)
Finite-lived intangible assets, net		798,089	772,287
INTANGIBLE ASSETS, net of accumulated amortization		800,889	775,087
Non-Amortizable
Gross carrying amount of intangible assets		$ 1,304,006	1,192,734
Weighted average remaining amortization period for intangible assets		11 years 4 months 24 days
Intangible assets written off related to the purchase of the remaining interest in a business			1,800
Revolving Credit Facility
Non-Amortizable
Write off of debt issuance costs				$ 4,500
Trade names
Non-Amortizable
Indefinite-lived intangible assets		$ 2,800	2,800
Trade names | Operating segment | Water solutions
Non-Amortizable
Write-off of intangible asset				$ 5,200
Customer relationships
Amortizable
Finite-lived intangible assets, gross		742,832	718,764
Accumulated amortization		(369,983)	(328,666)
Finite-lived intangible assets, net		$ 372,849	390,098
Customer relationships | Minimum
Amortizable
Amortizable life		3 years
Customer relationships | Maximum
Amortizable
Amortizable life		30 years
Customer commitments
Amortizable
Amortizable life		10 years
Finite-lived intangible assets, gross		$ 310,000	310,000
Accumulated amortization		(74,917)	(43,917)
Finite-lived intangible assets, net		$ 235,083	266,083
Pipeline capacity rights
Amortizable
Amortizable life		30 years
Finite-lived intangible assets, gross		$ 7,799	7,799
Accumulated amortization		(1,387)	(1,127)
Finite-lived intangible assets, net		6,412	6,672
Right-of-way and easements
Amortizable
Finite-lived intangible assets, gross		73,409	63,995
Accumulated amortization		(4,509)	(3,214)
Finite-lived intangible assets, net		$ 68,900	60,781
Right-of-way and easements | Minimum
Amortizable
Amortizable life		1 year
Right-of-way and easements | Maximum
Amortizable
Amortizable life		40 years
Water rights
Amortizable
Amortizable life		14 years
Finite-lived intangible assets, gross		$ 64,868	0
Accumulated amortization		(3,018)	0
Finite-lived intangible assets, net		61,850	0
Executory contracts and other agreements
Amortizable
Finite-lived intangible assets, gross		47,230	42,919
Accumulated amortization		(17,212)	(15,424)
Finite-lived intangible assets, net		$ 30,018	27,495
Executory contracts and other agreements | Minimum
Amortizable
Amortizable life		3 years
Executory contracts and other agreements | Maximum
Amortizable
Amortizable life		30 years
Non-compete agreements
Amortizable
Finite-lived intangible assets, gross		$ 12,723	5,465
Accumulated amortization		(2,570)	(706)
Finite-lived intangible assets, net		$ 10,153	4,759
Non-compete agreements | Minimum
Amortizable
Amortizable life		2 years
Non-compete agreements | Maximum
Amortizable
Amortizable life		32 years
Debt issuance costs
Amortizable
Amortizable life		5 years
Finite-lived intangible assets, gross		$ 42,345	40,992
Accumulated amortization		(29,521)	(24,593)
Finite-lived intangible assets, net		$ 12,824	$ 16,399
Water facility development agreement | Operating segment | Water solutions
Non-Amortizable
Impairment of intangible assets	$ 5,800

Intangible Assets - Amortizatio

Intangible Assets - Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Amortization related to intangible assets
Amortization expense	$ 115,872	$ 113,978	$ 96,230
Future amortization expense of intangible assets
2020	116,626
2021	104,512
2022	91,674
2023	83,654
2024	77,514
Thereafter	324,109
Finite-lived intangible assets, net	798,089	772,287
Depreciation and amortization
Amortization related to intangible assets
Amortization expense	110,458	108,444	89,765
Cost of sales
Amortization related to intangible assets
Amortization expense	486	966	1,994
Interest expense
Amortization related to intangible assets
Amortization expense	$ 4,928	$ 4,568	$ 4,471

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Feb. 22, 2017	Oct. 24, 2016	Jul. 09, 2014	Oct. 16, 2013	Jun. 19, 2012
Long-Term Debt
Face amount	$ 2,172,789	$ 2,701,031
Face amount, current portion	648	646
Face amount, long-term	2,172,141	2,700,385
LONG-TERM DEBT, debt issuance costs	(12,008)	(20,645)
Book value	2,160,781	2,680,386
Book value, current	648	646
LONG-TERM DEBT, net of debt issuance costs and current maturities	2,160,133	2,679,740
Amortization of debt issuance costs	4,300	6,100	$ 3,300
Expected Future Amortization of Debt Issuance Costs
2020	2,371
2021	2,367
2022	2,367
2023	2,367
2024	1,744
Thereafter	792
Total	$ 12,008
Senior secured notes
Long-Term Debt
Fixed interest rate								6.65%
5.125% Senior Notes due 2019
Long-Term Debt
Fixed interest rate	5.125%					5.125%
Face amount	$ 0	353,424
LONG-TERM DEBT, debt issuance costs	0	(1,653)
Book value	$ 0	351,771
6.875% Senior Notes due 2021
Long-Term Debt
Fixed interest rate	6.875%						6.875%
Face amount	$ 0	367,048
LONG-TERM DEBT, debt issuance costs	0	(4,499)
Book value	$ 0	362,549
7.50% Senior Notes due 2023
Long-Term Debt
Fixed interest rate	7.50%				7.50%
Face amount	$ 607,323	615,947
LONG-TERM DEBT, debt issuance costs	(6,916)	(8,542)
Book value	$ 600,407	607,405
6.125% Senior Notes due 2025
Long-Term Debt
Fixed interest rate	6.125%			6.125%
Face amount	$ 389,135	389,135
LONG-TERM DEBT, debt issuance costs	(5,092)	(5,951)
Book value	384,043	383,184
Other long-term debt
Long-Term Debt
Face amount	5,331	5,977
LONG-TERM DEBT, debt issuance costs	0	0
Book value	5,331	5,977
Expansion Capital Facility | Revolving Credit Facility
Long-Term Debt
Face amount	275,000	0
LONG-TERM DEBT, debt issuance costs	0	0
Book value	275,000	0
Working Capital Facility | Revolving Credit Facility
Long-Term Debt
Face amount	896,000	969,500
LONG-TERM DEBT, debt issuance costs	0	0
Book value	$ 896,000	$ 969,500

Long-Term Debt - Credit Agreeme

Long-Term Debt - Credit Agreement (Details) - USD ($) $ in Millions	Feb. 06, 2019	Jul. 05, 2018	Mar. 31, 2019
Long-Term Debt
Credit Agreement Amendment - February 6, 2019	we amended the Credit Agreement, to, among other things, reset the basket for the repurchase of common units with a limit of $150 million in aggregate during the remaining term of the Credit Agreement, not to exceed $50 million per fiscal quarter, so long as, both immediately before and after giving pro forma effect to the repurchases, the Partnership’s Leverage Ratio (as defined in the Credit Agreement) is less than 3.25x and Revolving Availability (also as defined in the Credit Agreement) is greater than or equal to $200 million. In addition, the amendment decreases the Maximum Total Leverage Indebtedness Ratio beginning September 30, 2019 with a further decrease beginning March 31, 2020 (as presented in the table below), and amends the defined term “Consolidated EBITDA” to exclude the “Gavilon Energy EPA Settlement” (as defined in the Credit Agreement) solely for the two quarters ending December 31, 2018 and March 31, 2019.
Revolving Credit Facility
Long-Term Debt
Maximum borrowing capacity			$ 1,765
Credit Agreement Amendment - July 5, 2018		In the amendment, the lenders consented to, subject to the consummation of the Retail Propane disposition, release NGL Propane, LLC and its wholly-owned subsidiaries from its guaranty and other obligations under the loan documents, among other things. In return, the Partnership agreed to use the net proceeds from the Retail Propane disposition to pay down existing indebtedness no later than five business days after the consummation of the Retail Propane disposition.
Financial Covenants in Credit Agreement
Debt instrument, actual leverage ratio			2.63
Debt instrument, actual senior secured leverage ratio			0.58
Debt instrument, actual interest coverage ratio			3.70
Debt instrument, actual total leverage indebtedness ratio			4.48
Revolving Credit Facility | Minimum
Long-Term Debt
Commitment fees charged on unused capacity			0.375%
Financial Covenants in Credit Agreement
Debt instrument, interest coverage ratio March 31, 2019 to October 5, 2021			2.75
Revolving Credit Facility | Maximum
Long-Term Debt
Commitment fees charged on unused capacity			0.50%
Financial Covenants in Credit Agreement
Debt instrument, leverage ratio March 31, 2019 to October 5, 2021			4.50
Debt instrument, senior secured leverage ratio March 31, 2019 to October 5, 2021			3.25
Debt instrument, total leverage indebtedness ratio March 31, 2019 to September 30, 2019			6.50
Debt instrument, total leverage indebtedness ratio September 30, 2019 to March 31, 2020			6.25
Debt instrument, total leverage indebtedness ratio March 31, 2020 to October 5, 2021			6
Revolving Credit Facility | LIBOR option
Long-Term Debt
Reference rate			2.49%
Interest rate margin added to variable rate base			1.75%
Revolving Credit Facility | Prime rate
Long-Term Debt
Reference rate			5.50%
Interest rate margin added to variable rate base			0.75%
Revolving Credit Facility
Long-Term Debt
Interest rate			4.39%
Working Capital Facility | Revolving Credit Facility
Long-Term Debt
Maximum borrowing capacity			$ 1,250
Working Capital Facility | Letters of credit
Long-Term Debt
Outstanding letters of credit			143.4
Expansion Capital Facility | Revolving Credit Facility
Long-Term Debt
Maximum borrowing capacity			$ 515
Letters of credit | Revolving Credit Facility
Long-Term Debt
Fixed interest rate			1.75%

Long Term Debt - Senior Secured

Long Term Debt - Senior Secured Notes (Details) - Senior secured notes - USD ($) $ in Thousands	Dec. 19, 2017	Mar. 31, 2018	Jun. 19, 2012
Long-Term Debt
Face amount			$ 250,000
Fixed interest rate			6.65%
Repayments in semi-annual installments	$ 19,500	$ 25,000
Notes repurchased		230,500
Cash paid (excluding payments of accrued interest)		250,179
Loss on early extinguishment of debt		(23,971)
Write off of debt issuance costs		$ 4,300

Long-Term Debt - Senior Unsecur

Long-Term Debt - Senior Unsecured Notes (Details) - USD ($) $ in Thousands	Apr. 09, 2019	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Feb. 22, 2017	Oct. 24, 2016	Jul. 09, 2014	Oct. 16, 2013
Long-Term Debt
2026 Notes redemption terms		We have the option to redeem all or a portion of the 2026 Notes at any time on or after April 15, 2022 at fixed redemption prices beginning at 103.750% on such date and declining annually and ratably to par for redemptions occurring on or after April 15, 2024 plus accrued and unpaid interest. At any time prior to April 15, 2022, we may redeem all or a portion of the 2026 Notes, at a redemption price equal to the “make whole price” specified in the indenture, plus accrued and unpaid interest.
2026 Notes registration rights agreement terms		If the Partnership fails to satisfy this obligation, it will be required to pay to the holders of the 2026 Notes liquidated damages in an amount equal 0.25% per annum on the principal amount of the 2026 Notes held by such holder during the 90-day period immediately following the occurrence of such registration default, and such amount shall increase by 0.25% per annum at the end of such 90-day period.
Notes repurchased		$ 737,058	$ 486,699	$ 21,193
5.125% Senior Notes due 2019
Long-Term Debt
Face amount							$ 400,000
Fixed interest rate		5.125%					5.125%
6.875% Senior Notes due 2021
Long-Term Debt
Face amount								$ 450,000
Fixed interest rate		6.875%						6.875%
7.50% Senior Notes due 2023
Long-Term Debt
Face amount						$ 700,000
Fixed interest rate		7.50%				7.50%
6.125% Senior Notes due 2025
Long-Term Debt
Face amount					$ 500,000
Fixed interest rate		6.125%			6.125%
7.50% Senior Notes due 2026
Long-Term Debt
Face amount	$ 450,000
Fixed interest rate	7.50%
Proceeds from issuance of 2026 Notes	$ 441,800
Initial purchaser's discount on 2026 Notes	6,800
Offering costs for 2026 Notes	$ 1,500
Redemptions | 5.125% Senior Notes due 2019
Long-Term Debt
Notes repurchased		$ 328,005
Cash paid (excluding payments of accrued interest)		329,719
Gain (loss) on extinguishment of debt		(2,113)
Write off of debt issuance costs		400
Redemptions | 6.875% Senior Notes due 2021
Long-Term Debt
Notes repurchased		367,048
Cash paid (excluding payments of accrued interest)		373,358
Gain (loss) on extinguishment of debt		(10,130)
Write off of debt issuance costs		3,800
Repurchases | 5.125% Senior Notes due 2019
Long-Term Debt
Notes repurchased		25,419	26,034	9,009
Cash paid (excluding payments of accrued interest)		25,406	26,002	7,099
Gain (loss) on extinguishment of debt		(34)	(140)	1,759
Write off of debt issuance costs		100	200	200
Repurchases | 6.875% Senior Notes due 2021
Long-Term Debt
Notes repurchased		0	0	21,241
Cash paid (excluding payments of accrued interest)		0	0	14,094
Gain (loss) on extinguishment of debt		0	0	6,748
Write off of debt issuance costs				400
Repurchases | 7.50% Senior Notes due 2023
Long-Term Debt
Notes repurchased		8,624	84,053	0
Cash paid (excluding payments of accrued interest)		8,575	83,967	0
Gain (loss) on extinguishment of debt		(63)	(1,136)	0
Write off of debt issuance costs		100	1,200
Repurchases | 6.125% Senior Notes due 2025
Long-Term Debt
Notes repurchased		0	110,865	0
Cash paid (excluding payments of accrued interest)		0	107,050	0
Gain (loss) on extinguishment of debt		$ 0	2,046	$ 0
Write off of debt issuance costs			$ 1,800

Long-Term Debt - Other Long-Ter

Long-Term Debt - Other Long-Term Debt (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2017	Mar. 31, 2019	Mar. 31, 2018
Long-Term Debt
Face amount		$ 2,172,789	$ 2,701,031
Equipment loan
Long-Term Debt
Face amount		$ 5,300
Repayments of debt	$ 41,700
Gain (loss) on extinguishment of debt	1,600
Write off of debt issuance costs	100
Other long-term debt repayment penalty	$ 1,500
Equipment loan | Minimum
Long-Term Debt
Fixed interest rate		4.13%
Equipment loan | Maximum
Long-Term Debt
Fixed interest rate		7.10%

Long-Term Debt - Debt Maturity

Long-Term Debt - Debt Maturity Schedule (Details) $ in Thousands	Mar. 31, 2019USD ($)
Maturities
2020	$ 648
2021	4,683
2022	1,171,000
2023	0
2024	607,323
Thereafter	389,135
Total	2,172,789
Revolving Credit Facility
Maturities
2022	1,171,000
2023	0
Total	1,171,000
Senior unsecured notes
Maturities
2023	0
2024	607,323
Thereafter	389,135
Total	996,458
Other long-term debt
Maturities
2020	648
2021	4,683
2022	0
2023	0
2024	0
Thereafter	0
Total	$ 5,331

Commitments and Contingencies -

Commitments and Contingencies - Legal Contingencies (Details) $ in Millions	12 Months Ended
	Mar. 31, 2019USD ($)
Loss Contingencies
Range of possible loss	$ 4
Loss contingency accrual	2.5
Services Rendered
Loss Contingencies
Damages awarded	4
Fraudulent Misrepresentation
Loss Contingencies
Damages awarded	$ 29

Commitments and Contingencies_2

Commitments and Contingencies - Environmental Matters (Details) $ in Thousands, number in Millions	12 Months Ended
	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)
Environmental matter
Environmental matters liability	$ 2,500
Litigation settlement, cash portion	$ 25,000
Litigation settlement, renewable identification numbers	36
Litigation settlement expense	$ 12,500
Estimated litigation liability	$ 12,500	$ 0

Commitments and Contingencies_3

Commitments and Contingencies - Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	$ 9,133	$ 8,181
Liabilities incurred	586	592
Liabilities assumed in acquisitions	438	21
Liabilities associated with disposed assets (1)	(585)
Liabilities settled	(546)	(549)
Accretion expense	697	888
Balance at end of period	$ 9,723	$ 9,133

Commitments and Contingencies_4

Commitments and Contingencies - Operating Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Future minimum lease payments
2020	$ 78,348
2021	60,417
2022	43,259
2023	29,252
2024	18,341
Thereafter	41,845
Total	271,462
Rental expense	$ 91,600	$ 111,300	$ 114,600

Commitments and Contingencies_5

Commitments and Contingencies - Pipeline Capacity Agreements (Details) $ in Millions	12 Months Ended
	Mar. 31, 2019USD ($)
Pipeline capacity agreements
Future minimum throughput payments
Future minimum throughput payments in 2020	$ 43.2
Third party pipeline capacity assumption
Future minimum throughput payments
Future minimum throughput payments in 2020	$ 30
Contract No. 1 | Customer contracts
Future minimum throughput payments
Number of months to continue shipping after maturity date of contract	6 months

Commitments and Contingencies_6

Commitments and Contingencies - Construction Commitments (Details) $ in Millions	Mar. 31, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
Construction commitments	$ 29.7

Commitments and Contingencies_7

Commitments and Contingencies - Purchase Commitments (Details) gal in Thousands, bbl in Thousands, $ in Thousands	Mar. 31, 2019USD ($)bblgal
Crude oil
Purchase commitments for crude oil and natural gas
Fixed-price purchase commitments, due in next twelve months	$ 60,227
Fixed-price purchase commitments (in barrels/gallons), due in next twelve months | bbl	1,040
Total fixed-price purchase commitments	$ 60,227
Total fixed-price purchase commitments (in barrels/gallons) | bbl	1,040
Index-price purchase commitments, due in next twelve months	$ 1,703,112
Index-price purchase commitments (in barrels/gallons), due in next twelve months | bbl	30,363
Index-price purchase commitments, due in second year	$ 526,420
Index-price purchase commitments (in barrels/gallons), due in second year | bbl	10,227
Index-price purchase commitments, due in third year	$ 411,071
Index-price purchase commitments (in barrels), due in third year | bbl	8,264
Index-price purchase commitments, due in fourth year	$ 269,990
Index-price purchase commitments (in barrels), due in fourth year | bbl	5,482
Index-price purchase commitments, due in fifth year	$ 200,022
Index-price purchase commitments (in barrels), due in fifth year | bbl	4,110
Total index-price purchase commitments	$ 3,110,615
Total index-price purchase commitments (in barrels/gallons) | bbl	58,446
Natural gas liquids
Purchase commitments for crude oil and natural gas
Fixed-price purchase commitments, due in next twelve months	$ 5,033
Fixed-price purchase commitments (in barrels/gallons), due in next twelve months | gal	7,545
Fixed-price purchase commitments, due in second year	$ 265
Fixed-price purchase commitments (in gallons), due in second year | gal	378
Total fixed-price purchase commitments	$ 5,298
Total fixed-price purchase commitments (in barrels/gallons) | gal	7,923
Index-price purchase commitments, due in next twelve months	$ 564,013
Index-price purchase commitments (in barrels/gallons), due in next twelve months | gal	1,023,998
Index-price purchase commitments, due in second year	$ 1,199
Index-price purchase commitments (in barrels/gallons), due in second year | gal	2,152
Total index-price purchase commitments	$ 565,212
Total index-price purchase commitments (in barrels/gallons) | gal	1,026,150

Commitments and Contingencies_8

Commitments and Contingencies - Sales Commitments (Details) gal in Thousands, bbl in Thousands, $ in Thousands	Mar. 31, 2019USD ($)bblgal	Mar. 31, 2018USD ($)
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 7,700	$ (7,037)
Crude oil
Sales commitments for crude oil and natural gas
Fixed-price sale commitments, due in next twelve months	$ 63,759
Fixed-price sales commitments (in barrels/gallons), due in next twelve months | bbl	1,090
Total fixed-price sale commitments	$ 63,759
Total fixed-price sale commitments (in barrels/gallons) | bbl	1,090
Index-price sale commitments, due in next twelve months	$ 1,240,074
Index-price sale commitments (in barrels/gallons), due in next twelve months | bbl	20,500
Total index-price sale commitments	$ 1,240,074
Total index-price sale commitments (in barrels/gallons) | bbl	20,500
Natural gas liquids
Sales commitments for crude oil and natural gas
Fixed-price sale commitments, due in next twelve months	$ 45,626
Fixed-price sales commitments (in barrels/gallons), due in next twelve months | gal	52,766
Fixed-price sale commitments, due in second year	$ 1,395
Fixed-price sale commitments (in gallons), due in second year | gal	1,580
Fixed-price sale commitments, due in third year	$ 86
Fixed-price sale commitments (in gallons), due in third year | gal	100
Total fixed-price sale commitments	$ 47,107
Total fixed-price sale commitments (in barrels/gallons) | gal	54,446
Index-price sale commitments, due in next twelve months	$ 594,877
Index-price sale commitments (in barrels/gallons), due in next twelve months | gal	778,454
Index-price sale commitments, due in second year	$ 1,634
Index-price commitments (in gallons), due in second year | gal	2,183
Total index-price sale commitments	$ 596,511
Total index-price sale commitments (in barrels/gallons) | gal	780,637
Prepaid expenses and other current assets
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 8,600
Accrued expenses and other payables
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 4,900

Equity - Partnership Equity and

Equity - Partnership Equity and General Partner Contributions (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Equity
General partner interest	0.10%	0.10%
Limited partner interest	99.90%	99.90%
General partners' capital account, notional units issued (in units)	3,039	1,294	16,026
Notional units issued		$ 202,731	$ 287,136
Common units
Equity
General partner interest	0.10%	0.10%	0.10%
Limited partner interest	99.90%
General Partner
Equity
Notional units issued	$ 100	$ 100	$ 288

Equity - Equity Issuances (Deta

Equity - Equity Issuances (Details) - USD ($) $ in Thousands	Feb. 22, 2017	Aug. 24, 2016	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Equity
Proceeds from sale of common units, net of offering costs			$ 0	$ 0	$ 287,136
Common units
Equity
Aggregate offering price under at the market program		$ 200,000
Units issued (in units)	10,120,000				3,321,135
Proceeds from sale of common units, net of offering costs	$ 222,500				$ 64,400
Limited partners' offering costs	$ 11,800				$ 900
Aggregate offering price remaining for sale			$ 134,700

Equity - Common Unit Repurchase

Equity - Common Unit Repurchase Programs (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Dec. 31, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Aug. 29, 2017
Common unit repurchases and cancellations		$ (297)	$ (15,817)	$ 0
Share repurchase program
Common unit repurchase program, authorized amount					$ 15,000
Common unit repurchases (in units)	1,516,848
Common unit repurchases and cancellations	$ (15,000)

Equity - Distributions (Details

Equity - Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	May 15, 2019	May 10, 2019	Apr. 24, 2019	Apr. 15, 2019	Feb. 14, 2019	Jan. 22, 2019	Jan. 15, 2019	Nov. 14, 2018	Oct. 23, 2018	Oct. 15, 2018	Aug. 14, 2018	Jul. 24, 2018	Jul. 16, 2018	May 15, 2018	Apr. 24, 2018	Apr. 16, 2018	Feb. 14, 2018	Jan. 23, 2018	Jan. 15, 2018	Nov. 14, 2017	Oct. 19, 2017	Oct. 16, 2017	Aug. 14, 2017	Jul. 20, 2017	May 15, 2017	Apr. 24, 2017	Feb. 14, 2017	Jan. 19, 2017	Nov. 14, 2016	Oct. 20, 2016	Aug. 12, 2016	Jul. 21, 2016	May 13, 2016	Apr. 21, 2016
Distributions
Amount Per Unit (in dollars per unit)			$ 0.3900			$ 0.3900			$ 0.3900			$ 0.3900			$ 0.3900			$ 0.3900			$ 0.3900			$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900
Amount Paid to Limited Partners	$ 49,127				$ 48,373			$ 48,260			$ 47,600			$ 47,374			$ 47,223			$ 47,000			$ 47,460		$ 46,870		$ 42,923		$ 41,907		$ 41,146		$ 40,626
Amount Paid to General Partner	$ 85				83			83			82			82			81			81			81		80		74		72		71		$ 70
Class B Perpetual Preferred Units
Distributions
Distributions paid to preferred unitholders				$ 4,725			$ 4,725			$ 4,725			$ 4,725			$ 4,725			$ 4,725			$ 5,670
Oaktree Capital Management L.P. | Class A Convertible Preferred Units
Distributions
Distributions paid to preferred unitholders		$ 4,034			$ 6,449			$ 6,449			$ 6,449			$ 6,449			$ 6,449			$ 6,449			$ 6,449		$ 6,449		$ 6,449		$ 6,449		$ 1,795

Equity - Class A Convertible Pr

Equity - Class A Convertible Preferred Units (Details) - USD ($)	May 11, 2019	Apr. 05, 2019	Apr. 26, 2018	Jun. 23, 2017	Apr. 21, 2016	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Jun. 30, 2016	Jun. 24, 2016	Jun. 23, 2016
Preferred Units
Repurchase of warrants						$ 14,988,000	$ 10,549,000	$ 0
Allocation of value to beneficial conversion feature of Class A convertible preferred units (Note 10)								131,534,000
Accretion of beneficial conversion feature						$ 67,239,000	$ 18,781,000	8,999,000
Class A Convertible Preferred Units
Preferred Units
Preferred units dividend rate						10.75%	10.75%
Temporary equity, issued (in units)						19,942,169	19,942,169
Oaktree Capital Management L.P.
Preferred Units
Authorized amount					$ 200,000,000						$ 240,000,000
Warrants outstanding (in units)						1,458,371			4,375,112
Oaktree Capital Management L.P. | Warrant
Preferred Units
Class of warrant or right, term					8
Class of warrant or right, exercise price										$ 0.01
Warrants exercised and converted to common units (in units)		1,458,371				228,797	607,653
Proceeds from warrant exercises						$ 100,000	$ 100,000
Repurchase of warrants (in units)			1,229,575	850,716
Repurchase of warrants			$ 15,000,000	$ 10,500,000
Oaktree Capital Management L.P. | Class A Convertible Preferred Units
Preferred Units
Preferred units dividend rate					10.75%
Proceeds from sale of convertible preferred units and warrants, net of offering costs					$ 235,000,000
Offering costs					$ 5,000,000
Days after quarter end distribution paid					45 days
Preferred stock redemption premium percentage	110.00%	111.25%
Initial conversion price (in dollars per unit)					$ 12.035
Preferred Units Accrued but Unpaid Distributions	$ 0.1437	$ 0.338
Reset conversion price, trading days used for adjustment					15 days
Reset conversion price (in dollars per unit)					$ 5
Number of days within closing date of registration statement required to file within					180 days
Number of days after closing date registration statement declared effective					360 days
Proceeds from sale of preferred units, net of offering costs					$ 186,400,000
Allocation of value to beneficial conversion feature of Class A convertible preferred units (Note 10)					$ 131,500,000
Conversion period					3
Accretion of beneficial conversion feature						$ 67,200,000	$ 18,800,000	$ 9,000,000
Preferred units redeemed	12,473,191	7,468,978
Preferrred unit redemption price per unit excluding unpaid dividends	$ 13.2385	$ 13.389
Preferred unit redemption price per unit	$ 13.3822	$ 13.727
Preferred unit redemption amount	$ 166,900,000	$ 102,500,000
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after first, but prior to the second anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					140.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the second, but prior to the third anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					115.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the third, but prior to the eighth anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					110.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the eighth anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					101.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Prior to the first anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					140.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the first but prior to the second anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					130.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the second anniversary of the closing date
Preferred Units
Preferred stock redemption premium percentage					120.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Thereafter
Preferred Units
Preferred stock redemption premium percentage					101.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | First six-month period
Preferred Units
Percentage increase in dividend rate					0.25%
Payment default period					6
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Second six-month period
Preferred Units
Percentage increase in dividend rate					0.25%
Payment default period					6
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Warrant
Preferred Units
Proceeds from sale of preferred units, net of offering costs					$ 48,600,000
Maximum | Oaktree Capital Management L.P. | Class A Convertible Preferred Units
Preferred Units
Preferred units dividend rate					11.25%

Equity - Class B Preferred Unit

Equity - Class B Preferred Units (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 02, 2019	Jun. 13, 2017	Mar. 31, 2018	Mar. 31, 2017
Preferred Units
Units issued, net of offering costs (Note 10)			$ 202,731	$ 287,136
Preferred units, underwriting discounts and commissions	$ 1,400
Preferred units, offering costs	$ 500
Class B Perpetual Preferred Units
Preferred Units
Preferred units dividend rate		9.00%
Preferred unit par or stated value per share		$ 25
Preferred units, underwriting discounts and commissions		$ 6,600
Preferred units, offering costs		$ 700
Preferred units, redemption terms		At any time on or after July 1, 2022, we may redeem our Class B Preferred Units, in whole or in part, at a redemption price of $25.00 per Class B Preferred Unit plus an amount equal to all accumulated and unpaid distributions to, but not including, the date of redemption, whether or not declared. We may also redeem the Class B Preferred Units upon a change of control as defined in our partnership agreement. If we choose not to redeem the Class B Preferred Units, the Class B preferred unitholders may have the ability to convert the Class B Preferred Units to common units at the then applicable conversion rate. Class B preferred unitholders have no voting rights except with respect to certain matters set forth in our partnership agreement.
Preferred units, dividend payment terms		Distributions on the Class B Preferred Units are payable on the 15th day of each January, April, July and October of each year to holders of record on the first day of each payment month. The initial distribution rate for the Class B Preferred Units from and including the date of original issue to, but not including, July 1, 2022 is 9.00% per year of the $25.00 liquidation preference per unit (equal to $2.25 per unit per year). On and after July 1, 2022, distributions on the Class B Preferred Units will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR plus a spread of 7.213%.
Class B Perpetual Preferred Units
Preferred Units
Units issued, net of offering costs (Note 10)		$ 202,700
Class B Perpetual Preferred Units | Class B Perpetual Preferred Units
Preferred Units
Units issued (in units)		8,400,000

Equity - Class C Preferred Unit

Equity - Class C Preferred Units (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 02, 2019	Mar. 31, 2018	Mar. 31, 2017
Preferred Units
Units issued, net of offering costs (Note 10)		$ 202,731	$ 287,136
Preferred units, underwriting discounts and commissions	$ 1,400
Preferred units, offering costs	$ 500
Class C Perpetual Preferred Units
Preferred Units
Preferred units dividend rate	9.625%
Preferred unit par or stated value per share	$ 25
Preferred units, redemption terms	At any time on or after April 15, 2024, we may redeem our Class C Preferred Units, in whole or in part, at a redemption price of $25.00 per Class C Preferred Unit plus an amount equal to all accumulated and unpaid distributions to, but not including, the date of redemption, whether or not declared. We may also redeem the Class C Preferred Units upon a change of control as defined in our partnership agreement. If we choose not to redeem the Class C Preferred Units, the Class C preferred unitholders may have the ability to convert the Class C Preferred Units to common units at the then applicable conversion rate. Class C preferred unitholders have no voting rights except with respect to certain matters set forth in our partnership agreement.
Preferred units, dividend payment terms	Distributions on the Class C Preferred Units are payable on the 15th day of each January, April, July and October of each year to holders of record on the first day of each payment month. The initial distribution rate for the Class C Preferred Units from and including the date of original issue to, but not including, April 15, 2024, is 9.625% per year of the $25.00 liquidation preference per unit (equal to $2.41 per unit per year). On and after April 15, 2024, distributions on the Class C Preferred Units will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR plus a spread of 7.384%.
Class C Perpetual Preferred Units
Preferred Units
Units issued, net of offering costs (Note 10)	$ 43,100
Class C Perpetual Preferred Units | Class C Perpetual Preferred Units
Preferred Units
Units issued (in units)	1,800,000

Equity - Equity-Based Incentive

Equity - Equity-Based Incentive Compensation - Service Awards (Details) - USD ($)	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Mar. 31, 2016	Apr. 01, 2017
Equity-Based Incentive Compensation
Cumulative effect adjustment for adoption of ASC 606 (Note 15)	$ 139,306,000				$ 0
Cancellation of Common Units for Tax Withholding
Common units canceled during period (in units)	26,993
Value of common units canceled during period	$ 300,000
Deferred Compensation Arrangements
Deferred compensation units granted (in units)	176,817			1,008,091
Deferred compensation arrangement with individual, fair value of units issued	$ 2,400,000
Accrued bonuses		$ 6,300,000
Restricted units
Equity-Based Incentive Compensation
Distributions on restricted units during the vesting period	0
Service awards
Equity-Based Incentive Compensation
Expense recorded	$ 12,000,000	$ 16,200,000	$ 56,200,000
Service Award Activity
Unvested restricted units at the beginning of the period (in units)	2,278,875	2,708,500	2,297,132
Units granted (in units)	3,141,993	1,964,911	3,124,600
Units vested and issued (in units)	(2,833,968)	(2,260,011)	(2,350,082)
Units forfeited (in units)	(278,500)	(134,525)	(363,150)
Unvested restricted units at the end of the period (in units)	2,308,400	2,278,875	2,708,500	2,297,132
Deferred Compensation Arrangements
Deferred compensation arrangement with individual, fair value of units issued	$ 20,400,000	$ 700,000	$ 19,000,000
Accrued bonuses			2,200,000	$ 16,800,000
Expected Future Expense
2020	8,168,000
2021	4,154,000
2022	1,350,000
Total	$ 13,672,000
Service awards | 2020
Service Award Activity
Units vested and issued (in units)	(1,005,725)
Service awards | 2021
Service Award Activity
Units vested and issued (in units)	(869,425)
Service awards | 2022
Service Award Activity
Units vested and issued (in units)	(433,250)
Performance awards
Equity-Based Incentive Compensation
Expense recorded	$ 4,900,000	$ 5,300,000	$ 7,200,000
Service Award Activity
Unvested restricted units at the beginning of the period (in units)	917,000	1,189,000	637,382
Units granted (in units)		224,000	932,309
Units forfeited (in units)	(445,500)	(496,000)	(380,691)
Unvested restricted units at the end of the period (in units)	0	917,000	1,189,000	637,382
Deferred Compensation, Share-based Payments | Deferred Compensation, Share-based Payments
Deferred Compensation Arrangements
Deferred compensation units granted (in units)		59,393
Deferred Compensation, Share-based Payments | Deferred Bonus
Deferred Compensation Arrangements
Deferred compensation units granted (in units)		1,745,801

Equity - Equity-Based Incenti_2

Equity - Equity-Based Incentive Compensation - Performance Awards (Details) - Performance awards - USD ($) $ in Millions	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Performance Award Activity
Unvested restricted units at the beginning of the period (in units)	917,000	1,189,000	637,382
Units granted (in units)		224,000	932,309
Units forfeited (in units)	(445,500)	(496,000)	(380,691)
Units canceled	(471,500)
Unvested restricted units at the end of the period (in units)	0	917,000	1,189,000
Expense recorded	$ 4.9	$ 5.3	$ 7.2
Vesting on July 1, 2018
Performance Award Activity
Units vested and issued (in units)	0
General and Administrative Expense
Performance Award Activity
Expense recorded	$ 3.1

Equity - Equity-Based Compensat

Equity - Equity-Based Compensation - LTIP (Details) shares in Millions	12 Months Ended
	Mar. 31, 2019shares
LTIP
Percentage of outstanding stock maximum	10.00%
Incremental percentage of outstanding stock, maximum	10.00%
Restricted units
LTIP
Number of units available for grant	3.3

Fair Value of Financial Instr_3

Fair Value of Financial Instruments - Fair Value of Commodity Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Mar. 31, 2018
Derivative assets (liabilities)
Net commodity derivative asset (liability)	$ 7,700	$ (7,037)
Prepaid expenses and other current assets
Derivative assets (liabilities)
Net commodity derivative asset (liability)	8,600
Accrued expenses and other payables
Derivative assets (liabilities)
Net commodity derivative asset (liability)	4,900
Commodity contracts
Assets:
Derivative assets	12,636	9,848
Netting of counterparty contracts, assets	(1,577)	(664)
Net cash collateral provided (held)	1,740	(4,718)
Commodity derivatives	12,799	4,466
Liabilities:
Derivative liabilities	(6,468)	(15,909)
Netting of counterparty contracts, liabilities	1,577	664
Net cash collateral provided (held)	(208)	3,742
Commodity derivatives	(5,099)	(11,503)
Derivative assets (liabilities)
Net commodity derivative asset (liability)	7,700	(7,037)
Commodity contracts | Prepaid expenses and other current assets
Derivative assets (liabilities)
Net commodity derivative asset (liability)	12,799	4,466
Commodity contracts | Accrued expenses and other payables
Derivative assets (liabilities)
Net commodity derivative asset (liability)	(4,960)	(8,321)
Commodity contracts | Other noncurrent liabilities
Derivative assets (liabilities)
Net commodity derivative asset (liability)	(139)	(3,182)
Level 1 | Commodity contracts
Assets:
Derivative assets	3,754	2,835
Liabilities:
Derivative liabilities	(1,349)	(4,406)
Level 2 | Commodity contracts
Assets:
Derivative assets	8,882	7,013
Liabilities:
Derivative liabilities	$ (5,119)	$ (11,503)

Fair Value of Financial Instr_4

Fair Value of Financial Instruments - Derivative Contract Positions (Details) bbl in Thousands, $ in Thousands	Mar. 31, 2019USD ($)bbl	Mar. 31, 2018USD ($)bbl
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 6,168	$ (6,061)
Net cash collateral provided (held)	1,532	(976)
Net commodity derivative (liability) asset	7,700	(7,037)
Crude oil fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 979	$ (8,960)
Crude oil fixed-price | Short
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl	1,961	1,376
Propane fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 608	$ 1,849
Propane fixed-price | Long
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl	198	14
Refined products fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 376	$ 215
Refined products fixed-price | Short
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl	177	229
Cross-commodity
Derivative contract information
Fair Value of Net Assets (Liabilities)		$ (430)
Cross-commodity | Long
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl		155
Crude oil index
Derivative contract information
Fair Value of Net Assets (Liabilities)		$ (6)
Crude oil index | Short
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl		10
Refined products index
Derivative contract information
Fair Value of Net Assets (Liabilities)		$ (17)
Refined products index | Short
Derivative contract information
Net Long (Short) Notional Units (in barrels) | bbl		4
Other
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 4,205	$ 1,288

Fair Value of Financial Instr_5

Fair Value of Financial Instruments - Gains (Losses) From Commodity Derivatives (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Fair Value Disclosures [Abstract]
Net adjustments to fair value of commodity derivatives	$ 10,817	$ (41,263)	$ (15,376)

Fair Value of Financial Instr_6

Fair Value of Financial Instruments - Interest Rate Risk (Details) - Revolving Credit Facility $ in Billions	Mar. 31, 2019USD ($)
Interest Rate Risk
Outstanding debt	$ 1.2
Interest rate	4.39%

Fair Value of Financial Instr_7

Fair Value of Financial Instruments - Fair Value of Fixed-Rate Notes (Details) $ in Thousands	Mar. 31, 2019USD ($)
7.50% Senior Notes due 2023
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 626,621
6.125% Senior Notes due 2025
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 375,126

Segments (Details)

Segments (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Segment information
REVENUES	$ 2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	$ 8,689,157	$ 6,953,947	$ 5,216,265
Depreciation and amortization									211,973	208,398	179,613
Operating Income									126,728	187,335	226,469
Additions to property, plant and equipment and intangible assets									670,212	165,518	346,750
Long-lived assets, net	3,740,285				3,457,903				3,740,285	3,457,903
Total assets	5,902,493				6,151,122				5,902,493	6,151,122
Operating segment | Crude oil logistics
Segment information
REVENUES									3,136,635	2,260,075	1,666,884
Depreciation and amortization									74,165	80,387	54,144
Operating Income									(7,379)	122,904	(17,475)
Additions to property, plant and equipment and intangible assets									28,039	36,762	168,053
Long-lived assets, net	1,584,636				1,638,558				1,584,636	1,638,558
Total assets	2,237,612				2,285,813				2,237,612	2,285,813
Operating segment | Crude oil logistics | Crude oil sales
Segment information
REVENUES									3,011,355	2,151,203	1,603,667
Operating segment | Crude oil logistics | Crude oil transportation and other
Segment information
REVENUES									148,738	122,786	70,027
Operating segment | Crude oil logistics | Non-Topic 606 Revenues
Segment information
REVENUES									12,598	0	0
Operating segment | Water solutions
Segment information
REVENUES									301,686	229,139	159,601
Depreciation and amortization									108,162	98,623	101,758
Operating Income									210,525	(24,231)	44,587
Additions to property, plant and equipment and intangible assets									567,637	102,261	109,008
Long-lived assets, net	1,600,836				1,256,143				1,600,836	1,256,143
Total assets	1,668,292				1,323,171				1,668,292	1,323,171
Operating segment | Water solutions | Non-Topic 606 Revenues
Segment information
REVENUES									42	0	0
Operating segment | Water solutions | Service fees
Segment information
REVENUES									217,545	149,114	110,049
Operating segment | Water solutions | Recovered hydrocarbons
Segment information
REVENUES									72,678	58,948	31,103
Operating segment | Water solutions | Freshwater Revenues
Segment information
REVENUES									2,404	0	0
Operating segment | Water solutions | Other revenues
Segment information
REVENUES									9,017	21,077	18,449
Operating segment | Liquids
Segment information
REVENUES									2,415,041	2,215,985	1,537,172
Depreciation and amortization									25,997	24,937	19,163
Operating Income									(2,910)	(93,113)	43,252
Additions to property, plant and equipment and intangible assets									72,717	25,023	66,864
Long-lived assets, net	498,767				501,302				498,767	501,302
Total assets	721,008				717,690				721,008	717,690
Operating segment | Liquids | Non-Topic 606 Revenues
Segment information
REVENUES									21,608	0	0
Operating segment | Liquids | Other revenues
Segment information
REVENUES									26,655	22,548	32,648
Operating segment | Liquids | Propane sales
Segment information
REVENUES									1,169,117	1,203,486	807,172
Operating segment | Liquids | Butane sales
Segment information
REVENUES									628,063	562,066	391,265
Operating segment | Liquids | Other product sales
Segment information
REVENUES									592,889	432,570	308,031
Operating segment | Refined products and renewables
Segment information
REVENUES									2,834,433	2,247,574	1,851,764
Depreciation and amortization									631	672	936
Operating Income									12,198	261,249	243,090
Long-lived assets, net	29,477				30,384				29,477	30,384
Total assets	383,026				341,495				383,026	341,495
Operating segment | Refined products and renewables | Non-Topic 606 Revenues
Segment information
REVENUES									299,190	0	0
Operating segment | Refined products and renewables | Service fees
Segment information
REVENUES									0	(87)	0
Operating segment | Refined products and renewables | Refined products sales
Segment information
REVENUES									2,535,243	1,874,260	1,405,001
Operating segment | Refined products and renewables | Renewables sales
Segment information
REVENUES									0	373,669	447,232
Operating segment | Assets held for sale
Segment information
Total assets	815,536				1,380,742				815,536	1,380,742
Operating segment | Corporate, Non-Segment [Member]
Segment information
REVENUES									1,362	1,174	844
Operating segment | Corporate, Non-Segment [Member] | Non-Topic 606 Revenues
Segment information
REVENUES									1,362	1,174	844
Corporate, Non-Segment [Member]
Segment information
Depreciation and amortization									3,018	3,779	3,612
Operating Income									(85,706)	(79,474)	(86,985)
Additions to property, plant and equipment and intangible assets									1,819	1,472	2,825
Long-lived assets, net	26,569				31,516				26,569	31,516
Total assets	77,019				102,211				77,019	102,211
Elimination of intersegment sales | Crude oil logistics
Segment information
REVENUES									(36,056)	(13,914)	(6,810)
Elimination of intersegment sales | Liquids
Segment information
REVENUES									(23,291)	(4,685)	(1,944)
Elimination of intersegment sales | Refined products and renewables
Segment information
REVENUES									0	(268)	$ (469)
Non-US | Liquids
Segment information
Long-lived assets, net	500				600				500	600
Total assets	$ 12,000				$ 27,500				$ 12,000	$ 27,500

Transactions with Affiliates -

Transactions with Affiliates - Related Party Transactions (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Transactions with Affiliates
Accounts receivable-affiliates	$ 12,867	$ 4,772
Accounts payable-affiliates	28,469	1,254
WPX Energy
Transactions with Affiliates
Sales to related party	28,026	0	$ 0
Purchases from related party	329,525	0	0
Accounts receivable-affiliates	5,185	0
Accounts payable-affiliates	27,844	0
SemGroup
Transactions with Affiliates
Sales to related party	1,114	606	3,866
Purchases from related party	4,395	5,034	12,254
Accounts receivable-affiliates	71	49
Entities affiliated with management
Transactions with Affiliates
Sales to related party	21,385	268	290
Purchases from related party	4,382	3,870	15,209
Accounts receivable-affiliates	334	24
Accounts payable-affiliates	625	1,246
Equity method investees
Transactions with Affiliates
Sales to related party	0	294	692
Purchases from related party	0	66,820	$ 121,336
Accounts receivable-affiliates	0	6
Accounts payable-affiliates	0	8
NGL Energy Holdings LLC
Transactions with Affiliates
Accounts receivable-affiliates	$ 7,277	$ 4,693

Transactions with Affiliates _2

Transactions with Affiliates - Other Related Party Transactions (Details) - USD ($) $ in Thousands	Nov. 29, 2016	Jun. 03, 2016	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2016	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Aug. 14, 2018	Jul. 09, 2018	Mar. 31, 2016
Transactions with Affiliates
Ownership interest			50.00%			0.00%
Promissory note from Victory Propane									$ 3,400
Loan receivable from Victory Propane						$ 0	$ 1,200
Present value of note receivable from Victory Propane									2,600
Payments to acquire productive assets						455,586	133,761	$ 302,762
Carrying value						1,127	17,236		800
Repayments on loan to affiliate						0	4,160	655
Proceeds from sale of business						$ 335,809	329,780	$ 134,370
Crude oil logistics
Transactions with Affiliates
Write-off of pipeline deficiency credits			$ 67,700
Remaining deficiency payments			50,300
Loss on contract			$ 35,300
Victory Propane, LLC
Transactions with Affiliates
Cash paid				$ 6,400
Payments to acquire productive assets				6,424
Ownership interest acquired										40.00%
Grassland Water Solutions, LLC
Transactions with Affiliates
Ownership interest											35.00%
Repayments on loan to affiliate					$ 700
Ownership interest acquired		65.00%
Fair value of equity method investment		$ 800
Revaluation of investments excluding bargain purchase		(14,900)
Bargain purchase gain		600
Impairment of loan receivable from investee		$ 1,700
Proceeds from sale of business	$ 22,000
Loss on sale of business	$ 2,300
Customer relationships | Victory Propane, LLC
Transactions with Affiliates
Payments to acquire productive assets				4,782
Property, plant and equipment | Victory Propane, LLC
Transactions with Affiliates
Payments to acquire productive assets				1,366
Prepaid expenses and other current assets | Victory Propane, LLC
Transactions with Affiliates
Payments to acquire productive assets				$ 276
Equity method investees | Loan agreement
Transactions with Affiliates
Loan receivable from Victory Propane							$ 1,200		$ 2,600

Employee Benefit Plan (Details)

Employee Benefit Plan (Details) - USD ($) $ in Millions	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Defined Contribution Plan [Abstract]
Description of employee benefit plan	For every dollar that employees contribute up to 1% of their eligible compensation (as defined in the plan), we contribute one dollar, plus 50 cents for every dollar employees contribute between 1% and 6% of their eligible compensation (as defined in the plan). Our matching contributions prior to January 1, 2015 vest over five years and, effective January 1, 2015, our matching contributions vest over two years.
Defined contribution plan expense	$ 1.9	$ 1.7	$ 1.5

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Impact of Adoption (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017	Apr. 01, 2018
Revenue, Initial Application Period Cumulative Effect Transition
Accrued expenses and other payables	$ 107,759				$ 137,242				$ 107,759	$ 137,242
OTHER NONCURRENT LIABILITIES	63,542				173,324				63,542	173,324
General partner	(50,603)				(50,819)				(50,603)	(50,819)
Limited partners	2,067,197				1,852,495				2,067,197	1,852,495
Gain (loss) on disposition or impairment of assets, net									(34,296)	17,118	$ 208,982
Operating income									126,728	187,335	226,469
Net income (loss)	43,217	$ 110,528	$ 354,939	$ (169,289)	$ 110,912	$ 56,769	$ (173,579)	$ (63,707)	339,395	(69,605)	143,874
Net adjustments to fair value of commodity derivatives									10,817	(41,263)	(15,376)
Refined products and renewables
Revenue, Initial Application Period Cumulative Effect Transition
Net adjustments to fair value of commodity derivatives									4,200
General partner interest in TLP
Revenue, Initial Application Period Cumulative Effect Transition
Recognized portion of deferred gain on sale of general partner interest										$ 30,100	$ 30,100
Deferred gain on sale of general partner interest												$ 139,300
Revenue from Contract with Customer
Revenue, Initial Application Period Cumulative Effect Transition
Accrued expenses and other payables	107,759								107,759
OTHER NONCURRENT LIABILITIES	63,542								63,542
General partner	(50,603)								(50,603)
Limited partners	2,067,197								2,067,197
Gain (loss) on disposition or impairment of assets, net									34,296
Operating income									126,728
Net income (loss)									339,395
Calculated under Revenue Guidance in Effect before Topic 606
Revenue, Initial Application Period Cumulative Effect Transition
Accrued expenses and other payables	137,872								137,872
OTHER NONCURRENT LIABILITIES	142,623								142,623
General partner	(50,712)								(50,712)
Limited partners	1,958,113								1,958,113
Gain (loss) on disposition or impairment of assets, net									4,183
Operating income									156,841
Net income (loss)									369,508
Difference between Revenue Guidance in Effect before and after Topic 606
Revenue, Initial Application Period Cumulative Effect Transition
Accrued expenses and other payables	(30,113)								(30,113)
OTHER NONCURRENT LIABILITIES	(79,081)								(79,081)
General partner	109								109
Limited partners	$ 109,084								109,084
Gain (loss) on disposition or impairment of assets, net									30,113
Operating income									(30,113)
Net income (loss)									$ (30,113)

Revenue from Contracts with C_5

Revenue from Contracts with Customers - Performance Obligations (Details) $ in Thousands	Mar. 31, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 167,061
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 128,572
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 119,016
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 113,861
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 99,430
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue expected to be recognized as of March 31, 2019	$ 869,972

Revenue from Contracts with C_6

Revenue from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Apr. 01, 2018
Contract with Customer, Asset and Liability [Abstract]
Accounts receivable from contracts with customers	$ 613,827	$ 542,593
Contract liabilities balance	8,461	$ 7,889
Payment received and deferred	77,981
Payment recognized in revenue	$ (77,409)

Other Matters - Sale of South P

Other Matters - Sale of South Pecos Water Disposal Business (Details) - USD ($)	Feb. 28, 2019	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net		$ 335,809,000	$ 329,780,000	$ 134,370,000
Gain (loss) on disposition or impairment of assets, net		$ (34,296,000)	$ 17,118,000	$ 208,982,000
Water Solutions South Pecos Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net	$ 232,200,000
Gain (loss) on disposition or impairment of assets, net	$ (107,900,000)
Number of saltwater wells sold	9

Other Matters Other Matters - S

Other Matters Other Matters - Sale of Bakken Saltwater Disposal Business (Details) - USD ($)	Nov. 30, 2018	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net		$ 335,809,000	$ 329,780,000	$ 134,370,000
Gain (loss) on disposition or impairment of assets, net		$ (34,296,000)	$ 17,118,000	$ 208,982,000
Water Solutions Bakken Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net	$ 85,000,000
Gain (loss) on disposition or impairment of assets, net	$ (33,400,000)
Number of saltwater wells sold	5

Other Matters - Sawtooth Joint

Other Matters - Sawtooth Joint Venture (Details) $ in Thousands	Mar. 30, 2018USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)	Mar. 30, 2021USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from sale of business		$ 335,809	$ 329,780	$ 134,370
Sawtooth
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Noncontrolling interest, ownership interest percentage	28.50%
Proceeds from sale of business	$ 37,600
Intangible asset additions	$ 21,600
Parent, ownership interest percentage	71.50%
Subsequent Event | Sawtooth
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Time period to acquire additional ownership interest					2
Additional proceeds to acquire remaining interest					$ 182,400

Other Matters - Sale of Interes

Other Matters - Sale of Interest in Glass Mountain Pipeline, LLC (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2017	Mar. 31, 2019	Jun. 30, 2018	Sep. 30, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Ownership interest		0.00%	50.00%
Glass Mountain Pipeline, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from sale of interest in equity method investee	$ 292.1
Gain on sale of interest in equity method investee	$ (108.6)
Glass Mountain Pipeline, LLC | Operating segment | Crude oil logistics
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Ownership interest				50.00%

Other Matters - Termination of

Other Matters - Termination of a Storage Sublease Agreement (Details) $ in Thousands	12 Months Ended
	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Other Matters [Abstract]
Storage sublease agreement term			5
Storage sublease agreement number of payments			5
Storage sublease agreement period of benefit			4
Gain on termination of contract	$ 0	$ 0	$ 16,205

Other Matters - Termination o_2

Other Matters - Termination of Development Agreement (Details) $ in Thousands	Jun. 03, 2016USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Oil and Gas Delivery Commitments and Contracts
Payment to terminate contract		$ 0	$ 0	$ 16,875
Gain on termination of contract		0	0	16,205
Gain (loss) on disposition or impairment of assets, net		$ (34,296)	$ 17,118	208,982
Water solutions
Oil and Gas Delivery Commitments and Contracts
Payment to terminate contract	$ 49,600
Amortizable life	2
Increase in property, plant and equipment	$ 1,200
Intangible asset additions	3,300
Noncontrolling interest, increase from acquisition of assets	2,800
Payments for early extinguishment of liabilities	25,500			46,800
Release of liabilities, contract termination	$ 16,900
Gain on termination of contract				21,300
Gain (loss) on disposition or impairment of assets, net				$ 22,700

Other Matters - Sale of TLP Com

Other Matters - Sale of TLP Common Units (Details) - TLP $ in Millions	Apr. 01, 2016USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from sale of TLP common units	$ 112.4
Gain on sale of TLP common units	$ 104.1

Assets, Liabilities and Redee_3

Assets, Liabilities and Redeemable Noncontrolling Interest Held for Sale and Discontinued Operations (Details) $ in Thousands, gal in Millions	Sep. 30, 2019USD ($)	Jul. 10, 2018USD ($)	Mar. 30, 2018USD ($)	Dec. 31, 2019USD ($)	Mar. 31, 2019USD ($)bblgal	Mar. 31, 2018USD ($)bbl	Mar. 31, 2017USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net					$ 335,809	$ 329,780	$ 134,370
Gain (loss) on disposal of discontinued operations, net of tax					$ (407,608)	$ (88,194)	(196)
Number of barrels of refined product | bbl					389,737	366,212
Amount received from DCC and Superior for propane sales					$ 84,200
Disposal Group, Including Discontinued Operation, Balance Sheet Disclosures [Abstract]
Cash and cash equivalents					0	$ 4,113
Accounts receivable-trade, net					164,716	252,136
Inventories					327,015	402,904
Prepaid expenses and other current assets					89,254	49,518
Total current assets held for sale					580,985	708,671
Property, plant and equipment, net					15,553	207,661
Goodwill					35,405	142,028
Intangible assets, net					137,446	279,395
Other noncurrent assets (1)					46,147	42,987
Total noncurrent assets held for sale					234,551	672,071
Total assets held for sale					815,536	1,380,742
Accounts payable-trade					85,602	79,432
Accrued expenses and other payables					140,691	92,845
Advance payments received from customers					460	13,327
Current maturities of long-term debt					0	2,550
Total current liabilities held for sale					226,753	188,154
Long-term debt, net					0	2,888
Other noncurrent liabilities					33	190
Total noncurrent liabilities held for sale					33	3,078
Total liabilities held for sale					226,786	191,232
Redeemable noncontrolling interest					0	9,927
Total liabilities and redeemable noncontrolling interest held for sale					226,786	201,159
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Revenues					15,398,608	10,474,860	7,904,143
Cost of sales					15,338,614	10,418,447	7,681,429
Operating expenses					37,348	137,780	134,879
General and administrative expense					2,716	11,471	15,727
Depreciation and amortization					9,593	44,314	43,592
Gain (loss) on disposal of discontinued operations, net of tax					(407,608)	(88,194)	(196)
Operating income (loss) from discontinued operations					417,945	(48,958)	28,712
Equity in earnings (loss) of unconsolidated entities					1,183	425	(746)
Interest expense					(126)	(421)	(877)
Other income, net					837	1,930	1,244
Income (loss) from discontinued operations before taxes (2)					419,839	(47,024)	28,333
Income tax expense					(989)	(104)	(6)
Income (loss) from discontinued operations, net of tax					418,850	(47,128)	28,327
Discontinued operations income attributable to redeemable noncontrolling interests					$ (446)	1,030	$ 0
Propane sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Sale commitments (in gallons) | gal					7.4
Sale commitments					$ 5,700
TransMontaigne Product Services, LLC | Refined products and renewables
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net	$ 233,800
Gain (loss) on disposal of discontinued operations, net of tax				$ 181,200
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Gain (loss) on disposal of discontinued operations, net of tax				$ 181,200
Retail Propane Segment - West
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net			$ 212,400
Gain (loss) on disposal of discontinued operations, net of tax					1,300	(89,300)
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Gain (loss) on disposal of discontinued operations, net of tax					1,300	$ (89,300)
Retail Propane Segment - East
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net		$ 889,800
Gain (loss) on disposal of discontinued operations, net of tax					(408,900)
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Gain (loss) on disposal of discontinued operations, net of tax					$ (408,900)

Quarterly Financial Data (Una_3

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	$ 8,689,157	$ 6,953,947	$ 5,216,265
Total cost of sales	1,936,389	2,048,659	2,051,448	1,946,565	1,959,967	1,807,132	1,279,871	1,216,591	7,983,061	6,263,561	4,738,563
(Loss) income from continuing operations	57,867	97,202	(31,725)	(202,799)	(5,127)	105,035	(109,381)	(13,004)	(79,455)	(22,477)	115,547
Net (loss) income	43,217	110,528	354,939	(169,289)	110,912	56,769	(173,579)	(63,707)	339,395	(69,605)	143,874
Net (loss) income attributable to NGL Energy Partners LP	$ 62,253	$ 110,835	$ 355,505	$ (168,546)	$ 109,602	$ 56,256	$ (173,371)	$ (63,362)	$ 360,047	$ (70,875)	$ 137,042
BASIC INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations	$ 0.31	$ 0.55	$ (0.45)	$ (1.83)	$ (0.19)	$ 0.73	$ (1.03)	$ (0.19)	$ (1.39)	$ (0.68)	$ 0.73
Basic (loss) income per common unit	0.20	0.65	2.70	(1.55)	0.76	0.33	(1.56)	(0.61)	2.01	(1.08)	0.99
DILUTED INCOME (LOSS) PER COMMON UNIT
(Loss) income from continuing operations	0.31	0.54	(0.45)	(1.83)	(0.19)	0.71	(1.03)	(0.19)	(1.39)	(0.68)	0.70
Diluted (loss) income per common unit	$ 0.19	$ 0.64	$ 2.70	$ (1.55)	$ 0.76	$ 0.32	$ (1.56)	$ (0.61)	$ 2.01	$ (1.08)	$ 0.95
Basic weighted average common units outstanding (in units)	124,262,014	123,892,680	122,380,197	121,544,421	121,271,959	120,844,008	121,314,636	120,535,909	123,017,064	120,991,340	108,091,486
Diluted weighted average common units outstanding (in units)	126,926,589	125,959,751	122,380,197	121,544,421	121,271,959	124,161,966	121,314,636	120,535,909	123,017,064	120,991,340	111,850,621

Subsequent Events Subsequent Ev

Subsequent Events Subsequent Events (Details) $ in Millions	Jan. 31, 2020USD ($)	Jan. 03, 2020USD ($)	May 14, 2019USD ($)facility	Apr. 10, 2019USD ($)facility	Apr. 03, 2019USD ($)facility
Subsequent Event
Total consideration to acquire businesses			$ 892.5	$ 53	$ 13
Number of saltwater wells acquired | facility			35	3	2
Number of saltwater facilities acquired | facility				1
Mid-Con | Refined products and renewables
Subsequent Event
Payments made to sell business		$ 6.3
TransMontaigne Product Services, LLC | Refined products and renewables
Subsequent Event
Payments made to sell business	$ 41.7

Consolidating Guarantor and N_3

Consolidating Guarantor and Non-Guarantor Financial Information - Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Aug. 14, 2018	Mar. 31, 2018	Mar. 31, 2017	Mar. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents	$ 18,572		$ 22,094	$ 7,826	$ 24,536
Accounts receivable - trade, net of allowance for doubtful accounts	998,203		820,552
Accounts receivable-affiliates	12,867		4,772
Inventories	136,128		161,649
Prepaid expenses and other current assets	65,918		82,020
Assets held for sale	580,985		708,671
Total current assets	1,812,673		1,799,758
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,828,940		1,512,286
GOODWILL	1,110,456		1,170,530	1,287,212
INTANGIBLE ASSETS, net of accumulated amortization	800,889		775,087
INVESTMENTS IN UNCONSOLIDATED ENTITIES	1,127	$ 800	17,236
LOAN RECEIVABLE-AFFILIATE	0		1,200
OTHER NONCURRENT ASSETS	113,857		202,954
ASSETS HELD FOR SALE	234,551		672,071
Total assets	5,902,493		6,151,122
CURRENT LIABILITIES:
Accounts payable-trade	879,063		781,197
Accounts payable-affiliates	28,469		1,254
Accrued expenses and other payables	107,759		137,242
Advance payments received from customers	8,461		7,889
Current maturities of long-term debt	648		646
Liabilities held for sale	226,753		188,154
Total current liabilities	1,251,153		1,116,382
LONG-TERM DEBT, net of debt issuance costs and current maturities	2,160,133		2,679,740
OTHER NONCURRENT LIABILITIES	63,542		173,324
NONCURRENT LIABILITIES HELD FOR SALE	33		3,078
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS	149,814		82,576
REDEEMABLE NONCONTROLLING INTEREST HELD FOR SALE	0		9,927
EQUITY:
Partners' equity	2,219,325		2,004,407
Accumulated other comprehensive income (loss)	(255)		(1,815)
Noncontrolling interests	58,748		83,503
Total equity	2,277,818		2,086,095	2,166,802	1,694,065
Total liabilities and equity	5,902,493		6,151,122
Reportable Entity
CURRENT ASSETS:
Cash and cash equivalents				6,257
Reportable Entity | NGL Energy Partners LP (Parent)
CURRENT ASSETS:
Cash and cash equivalents	12,798		16,915	6,257	25,749
Total current assets	12,798		16,915
INTANGIBLE ASSETS, net of accumulated amortization	0		0
NET INTERCOMPANY RECEIVABLES (PAYABLES)	862,186		2,110,940
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	2,503,848		1,703,327
Total assets	3,378,832		3,831,182
CURRENT LIABILITIES:
Accounts payable-affiliates	1		1
Accrued expenses and other payables	25,497		41,104
Current maturities of long-term debt	0		0
Total current liabilities	25,498		41,105
LONG-TERM DEBT, net of debt issuance costs and current maturities	984,450		1,704,909
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS	149,814		82,576
EQUITY:
Partners' equity	2,219,070		2,002,592
Total equity	2,219,070		2,002,592
Total liabilities and equity	3,378,832		3,831,182
Reportable Entity | Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	3,728		3,329	73	(1,701)
Accounts receivable - trade, net of allowance for doubtful accounts	996,192		815,404
Accounts receivable-affiliates	12,867		4,772
Inventories	135,094		161,324
Prepaid expenses and other current assets	65,443		81,589
Assets held for sale	580,985		681,867
Total current assets	1,794,309		1,748,285
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,620,084		1,365,174
GOODWILL	1,105,281		1,093,270
INTANGIBLE ASSETS, net of accumulated amortization	725,542		691,382
INVESTMENTS IN UNCONSOLIDATED ENTITIES	1,127		17,236
NET INTERCOMPANY RECEIVABLES (PAYABLES)	(808,610)		(2,121,741)
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	170,690		244,109
LOAN RECEIVABLE-AFFILIATE			1,200
OTHER NONCURRENT ASSETS	113,857		202,954
ASSETS HELD FOR SALE	234,551		672,071
Total assets	4,956,831		3,913,940
CURRENT LIABILITIES:
Accounts payable-trade	872,122		778,965
Accounts payable-affiliates	28,468		1,253
Accrued expenses and other payables	80,765		94,853
Advance payments received from customers	7,550		4,022
Current maturities of long-term debt	648		646
Liabilities held for sale	226,753		175,640
Total current liabilities	1,216,306		1,055,379
LONG-TERM DEBT, net of debt issuance costs and current maturities	1,175,683		974,831
OTHER NONCURRENT LIABILITIES	60,961		167,398
NONCURRENT LIABILITIES HELD FOR SALE	33		3,078
REDEEMABLE NONCONTROLLING INTEREST HELD FOR SALE			9,927
EQUITY:
Partners' equity	2,503,848		1,704,896
Accumulated other comprehensive income (loss)	0		(1,569)
Noncontrolling interests	0
Total equity	2,503,848		1,703,327
Total liabilities and equity	4,956,831		3,913,940
Reportable Entity | Non-Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	2,046		1,850	$ 1,496	$ 488
Accounts receivable - trade, net of allowance for doubtful accounts	2,011		5,148
Accounts receivable-affiliates	0		0
Inventories	1,034		325
Prepaid expenses and other current assets	475		431
Assets held for sale			26,804
Total current assets	5,566		34,558
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	208,856		147,112
GOODWILL	5,175		77,260
INTANGIBLE ASSETS, net of accumulated amortization	75,347		83,705
INVESTMENTS IN UNCONSOLIDATED ENTITIES	0		0
NET INTERCOMPANY RECEIVABLES (PAYABLES)	(53,576)		10,801
OTHER NONCURRENT ASSETS	0		0
Total assets	241,368		353,436
CURRENT LIABILITIES:
Accounts payable-trade	6,941		2,232
Accounts payable-affiliates	0		0
Accrued expenses and other payables	1,497		1,285
Advance payments received from customers	911		3,867
Current maturities of long-term debt	0		0
Liabilities held for sale			12,514
Total current liabilities	9,349		19,898
LONG-TERM DEBT, net of debt issuance costs and current maturities	0		0
OTHER NONCURRENT LIABILITIES	2,581		5,926
EQUITY:
Partners' equity	229,693		327,858
Accumulated other comprehensive income (loss)	(255)		(246)
Total equity	229,438		327,612
Total liabilities and equity	241,368		353,436
Consolidating Adjustments
CURRENT ASSETS:
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	(2,674,538)		(1,947,436)
Total assets	(2,674,538)		(1,947,436)
EQUITY:
Partners' equity	(2,733,286)		(2,030,939)
Noncontrolling interests	58,748		83,503
Total equity	(2,674,538)		(1,947,436)
Total liabilities and equity	$ (2,674,538)		$ (1,947,436)

Consolidating Guarantor and N_4

Consolidating Guarantor and Non-Guarantor Financial Information - Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Consolidating Statement of Operations
REVENUES	$ 2,123,154	$ 2,295,369	$ 2,215,682	$ 2,054,952	$ 2,143,992	$ 1,996,370	$ 1,452,072	$ 1,361,513	$ 8,689,157	$ 6,953,947	$ 5,216,265
COST OF SALES	1,936,389	2,048,659	2,051,448	1,946,565	1,959,967	1,807,132	1,279,871	1,216,591	7,983,061	6,263,561	4,738,563
OPERATING COSTS AND EXPENSES:
Operating									231,065	193,076	173,046
General and administrative									107,407	97,979	100,839
Depreciation and amortization									211,973	208,398	179,613
Loss (gain) on disposal or impairment of assets, net									34,296	(17,118)	(208,982)
Revaluation of liabilities									(5,373)	20,716	6,717
Operating Income									126,728	187,335	226,469
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities									2,533	7,539	3,830
Revaluation of investments									0	0	(14,365)
Interest expense									(164,725)	(199,149)	(149,601)
(Loss) gain on early extinguishment of liabilities, net									(12,340)	(23,201)	24,727
Other (expense) income, net									(30,418)	6,352	26,420
(Loss) Income From Continuing Operations Before Income Taxes									(78,222)	(21,124)	117,480
INCOME TAX EXPENSE									(1,233)	(1,353)	(1,933)
(Loss) Income From Continuing Operations	57,867	97,202	(31,725)	(202,799)	(5,127)	105,035	(109,381)	(13,004)	(79,455)	(22,477)	115,547
Income (Loss) From Discontinued Operations, net of Tax									418,850	(47,128)	28,327
Net Income (Loss)	43,217	110,528	354,939	(169,289)	110,912	56,769	(173,579)	(63,707)	339,395	(69,605)	143,874
LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS									20,206	(240)	(6,832)
Net income attributable to redeemable noncontrolling interest									446	(1,030)	0
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	$ 62,253	$ 110,835	$ 355,505	$ (168,546)	$ 109,602	$ 56,256	$ (173,371)	$ (63,362)	360,047	(70,875)	137,042
Reportable Entity | NGL Energy Partners LP (Parent)
OTHER INCOME (EXPENSE):
Interest expense									(104,716)	(142,159)	(91,259)
(Loss) gain on early extinguishment of liabilities, net									(12,340)	(23,201)	8,507
(Loss) Income From Continuing Operations Before Income Taxes									(117,056)	(165,360)	(82,752)
EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES									477,103	94,485	219,794
(Loss) Income From Continuing Operations									360,047	(70,875)	137,042
Net Income (Loss)									360,047	(70,875)	137,042
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP									360,047	(70,875)	137,042
Reportable Entity | Guarantor Subsidiaries
Consolidating Statement of Operations
REVENUES									8,665,597	6,935,485	5,197,416
COST OF SALES									7,986,019	6,263,562	4,738,820
OPERATING COSTS AND EXPENSES:
Operating									217,597	186,056	166,519
General and administrative									106,595	97,402	100,436
Depreciation and amortization									201,513	197,497	172,172
Loss (gain) on disposal or impairment of assets, net									(31,924)	(133,993)	(208,982)
Revaluation of liabilities									(5,373)	20,124	6,305
Operating Income									191,170	304,837	222,146
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities									2,533	7,539	3,830
Revaluation of investments											(14,365)
Interest expense									(60,008)	(56,989)	(58,214)
(Loss) gain on early extinguishment of liabilities, net									0	0	16,220
Other (expense) income, net									(30,187)	7,152	27,013
(Loss) Income From Continuing Operations Before Income Taxes									103,508	262,539	196,630
INCOME TAX EXPENSE									(1,233)	(1,353)	(1,933)
EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES									(44,865)	(116,224)	(1,336)
(Loss) Income From Continuing Operations									57,410	144,962	193,361
Income (Loss) From Discontinued Operations, net of Tax									419,693	(50,477)	26,433
Net Income (Loss)									477,103	94,485	219,794
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP									477,103	94,485	219,794
Reportable Entity | Non-Guarantor Subsidiaries
Consolidating Statement of Operations
REVENUES									27,542	19,954	19,639
COST OF SALES									1,024	1,491	533
OPERATING COSTS AND EXPENSES:
Operating									13,468	7,020	6,527
General and administrative									812	577	403
Depreciation and amortization									10,460	10,901	7,441
Loss (gain) on disposal or impairment of assets, net									66,220	116,875	0
Revaluation of liabilities									0	592	412
Operating Income									(64,442)	(117,502)	4,323
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities										0	0
Interest expense									(46)	(46)	(174)
Other (expense) income, net									0	19	0
(Loss) Income From Continuing Operations Before Income Taxes									(64,488)	(117,529)	4,149
INCOME TAX EXPENSE										0	0
(Loss) Income From Continuing Operations									(64,488)	(117,529)	4,149
Income (Loss) From Discontinued Operations, net of Tax									(1,029)	2,575	1,347
Net Income (Loss)									(65,517)	(114,954)	5,496
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP									(65,517)	(114,954)	5,496
Consolidating Adjustments
Consolidating Statement of Operations
REVENUES									(3,982)	(1,492)	(790)
COST OF SALES									(3,982)	(1,492)	(790)
OPERATING COSTS AND EXPENSES:
Operating											0
Operating Income									0	0	0
OTHER INCOME (EXPENSE):
Interest expense									45	45	46
Other (expense) income, net									(231)	(819)	(593)
(Loss) Income From Continuing Operations Before Income Taxes									(186)	(774)	(547)
EQUITY IN NET INCOME (LOSS) FROM CONTINUING OPERATIONS OF CONSOLIDATED SUBSIDIARIES									(432,238)	21,739	(218,458)
(Loss) Income From Continuing Operations									(432,424)	20,965	(219,005)
Income (Loss) From Discontinued Operations, net of Tax									186	774	547
Net Income (Loss)									(432,238)	21,739	(218,458)
LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS									20,206	(240)	(6,832)
Net income attributable to redeemable noncontrolling interest									446	(1,030)
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP									$ (411,586)	$ 20,469	$ (225,290)

Consolidating Guarantor and N_5

Consolidating Guarantor and Non-Guarantor Financial Information - Statements of Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
Consolidating Statement of Comprehensive Income
Net (loss) income	$ 43,217	$ 110,528	$ 354,939	$ (169,289)	$ 110,912	$ 56,769	$ (173,579)	$ (63,707)	$ 339,395	$ (69,605)	$ 143,874
Other comprehensive (loss) income									(9)	13	(1,671)
Comprehensive income (loss)									339,386	(69,592)	142,203
Reportable Entity | NGL Energy Partners LP (Parent)
Consolidating Statement of Comprehensive Income
Net (loss) income									360,047	(70,875)	137,042
Comprehensive income (loss)									360,047	(70,875)	137,042
Reportable Entity | Guarantor Subsidiaries
Consolidating Statement of Comprehensive Income
Net (loss) income									477,103	94,485	219,794
Other comprehensive (loss) income									(18)	58	(1,626)
Comprehensive income (loss)									477,085	94,543	218,168
Reportable Entity | Non-Guarantor Subsidiaries
Consolidating Statement of Comprehensive Income
Net (loss) income									(65,517)	(114,954)	5,496
Other comprehensive (loss) income									9	(45)	(45)
Comprehensive income (loss)									(65,508)	(114,999)	5,451
Consolidating Adjustments
Consolidating Statement of Comprehensive Income
Net (loss) income									(432,238)	21,739	(218,458)
Comprehensive income (loss)									$ (432,238)	$ 21,739	$ (218,458)

Consolidating Guarantor and N_6

Consolidating Guarantor and Non-Guarantor Financial Information - Statements of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2017
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities-continuing operations	$ 151,523	$ 300,348	$ 17,856
Net cash provided by (used in) operating activities-discontinued operations	185,727	(162,381)	(42,894)
Net cash provided by (used in) operating activities	337,250	137,967	(25,038)
INVESTING ACTIVITIES:
Capital expenditures	(455,586)	(133,761)	(302,762)
Acquisitions, net of cash acquired	(300,614)	(19,897)	(41,928)
Net settlements of commodity derivatives	(10,173)	(39,113)	9,648
Proceeds from sales of assets	16,177	33,844	28,232
Proceeds from divestitures of businesses and investments, net	335,809	329,780	134,370
Transaction with Victory Propane (Note 13)	0	(6,424)	0
Investments in unconsolidated entities	(389)	(21,465)	(2,105)
Distributions of capital from unconsolidated entities	1,440	11,969	9,692
Repayments on loan for natural gas liquids facility	10,336	10,052	8,916
Loan to affiliate	(1,515)	(2,510)	(3,200)
Repayments on loan to affiliate	0	4,160	655
Payment to terminate development agreement	0	0	(16,875)
Net cash (used in) provided by investing activities-continuing operations	(404,515)	166,635	(175,357)
Net cash provided by (used in) investing activities-discontinued operations	857,988	103,947	(187,769)
Net cash (used in) provided by investing activities	453,473	270,582	(363,126)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	4,098,500	2,434,500	1,700,000
Payments on revolving credit facilities	(3,897,000)	(2,279,500)	(2,733,500)
Issuance of senior unsecured notes	0	0	1,200,000
Repayment and repurchase of senior secured and senior unsecured notes	(737,058)	(486,699)	(21,193)
Payments on other long-term debt	(653)	(877)	(46,153)
Debt issuance costs	(1,383)	(2,700)	(33,558)
Contributions from general partner	0	0	49
Contributions from noncontrolling interest owners, net	169	23	672
Distributions to general and common unit partners and preferred unitholders	(236,633)	(225,067)	(181,581)
Distributions to noncontrolling interest owners	0	(3,082)	(3,292)
Proceeds from sale of preferred units, net of offering costs	0	202,731	234,975
Repurchase of warrants	(14,988)	(10,549)	0
Common unit repurchases and cancellations	(297)	(15,817)	0
Proceeds from sale of common units, net of offering costs	0	0	287,136
Payments for settlement and early extinguishment of liabilities	(4,577)	(3,408)	(28,468)
Net cash (used in) provided by financing activities-continuing operations	(793,920)	(390,445)	375,087
Net cash used in financing activities-discontinued operations	(325)	(3,836)	(3,633)
Net cash (used in) provided by financing activities	(794,245)	(394,281)	371,454
Net (decrease) increase in cash and cash equivalents	(3,522)	14,268	(16,710)
Cash and cash equivalents, beginning of period	22,094	7,826	24,536
Cash and cash equivalents, end of period	18,572	22,094	7,826
Reportable Entity
FINANCING ACTIVITIES:
Cash and cash equivalents, beginning of period		6,257
Cash and cash equivalents, end of period			6,257
Reportable Entity | NGL Energy Partners LP (Parent)
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities-continuing operations	(116,033)	(141,967)	(749,250)
Net cash provided by (used in) operating activities	(116,033)	(141,967)	(749,250)
FINANCING ACTIVITIES:
Issuance of senior unsecured notes			1,200,000
Repayment and repurchase of senior secured and senior unsecured notes	(737,058)	(486,699)	(21,193)
Debt issuance costs	(30)	(692)	(21,868)
Contributions from general partner			49
Distributions to general and common unit partners and preferred unitholders	(236,633)	(225,067)	(181,581)
Proceeds from sale of preferred units, net of offering costs		202,731	234,975
Repurchase of warrants	(14,988)	(10,549)
Common unit repurchases and cancellations	(297)	(15,817)
Proceeds from sale of common units, net of offering costs			287,136
Net changes in advances with consolidated entities	1,100,922	688,718	(767,760)
Net cash (used in) provided by financing activities-continuing operations	111,916	152,625	729,758
Net cash (used in) provided by financing activities	111,916	152,625	729,758
Net (decrease) increase in cash and cash equivalents	(4,117)	10,658	(19,492)
Cash and cash equivalents, beginning of period	16,915	6,257	25,749
Cash and cash equivalents, end of period	12,798	16,915	6,257
Reportable Entity | Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities-continuing operations	295,293	433,678	750,978
Net cash provided by (used in) operating activities-discontinued operations	182,506	(165,862)	(47,923)
Net cash provided by (used in) operating activities	477,799	267,816	703,055
INVESTING ACTIVITIES:
Capital expenditures	(414,522)	(130,760)	(296,395)
Acquisitions, net of cash acquired	(296,687)	3,100	(41,928)
Net settlements of commodity derivatives	(10,173)	(39,113)	9,648
Proceeds from sales of assets	16,177	33,844	28,232
Proceeds from divestitures of businesses and investments, net	335,809	292,112	112,370
Transaction with Victory Propane (Note 13)		(6,424)
Investments in unconsolidated entities	(389)	(21,465)	(2,105)
Distributions of capital from unconsolidated entities	1,440	11,969	9,692
Repayments on loan for natural gas liquids facility	10,336	10,052	8,916
Loan to affiliate	(1,515)	(2,510)	(3,200)
Repayments on loan to affiliate		4,160	655
Payment to terminate development agreement			(16,875)
Net cash (used in) provided by investing activities-continuing operations	(359,524)	154,965	(190,990)
Net cash provided by (used in) investing activities-discontinued operations	851,006	104,666	(175,371)
Net cash (used in) provided by investing activities	491,482	259,631	(366,361)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	4,098,500	2,434,500	1,700,000
Payments on revolving credit facilities	(3,897,000)	(2,279,500)	(2,733,500)
Payments on other long-term debt	(653)	(877)	(46,153)
Debt issuance costs	(1,353)	(2,008)	(11,690)
Payments for settlement and early extinguishment of liabilities	(4,577)	(3,408)	(28,468)
Net changes in advances with consolidated entities	(1,163,504)	(669,452)	788,334
Net cash (used in) provided by financing activities-continuing operations	(968,587)	(520,745)	(331,477)
Net cash used in financing activities-discontinued operations	(295)	(3,446)	(3,443)
Net cash (used in) provided by financing activities	(968,882)	(524,191)	(334,920)
Net (decrease) increase in cash and cash equivalents	399	3,256	1,774
Cash and cash equivalents, beginning of period	3,329	73	(1,701)
Cash and cash equivalents, end of period	3,728	3,329	73
Reportable Entity | Non-Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities-continuing operations	(27,551)	9,411	16,675
Net cash provided by (used in) operating activities-discontinued operations	3,221	3,481	5,029
Net cash provided by (used in) operating activities	(24,330)	12,892	21,704
INVESTING ACTIVITIES:
Capital expenditures	(41,064)	(3,001)	(6,367)
Acquisitions, net of cash acquired	(3,927)	(22,997)
Proceeds from divestitures of businesses and investments, net		37,668	22,000
Net cash (used in) provided by investing activities-continuing operations	(44,991)	11,670	15,633
Net cash provided by (used in) investing activities-discontinued operations	6,982	(719)	(12,398)
Net cash (used in) provided by investing activities	(38,009)	10,951	3,235
FINANCING ACTIVITIES:
Contributions from noncontrolling interest owners, net	169	23	672
Distributions to noncontrolling interest owners		(3,082)	(3,292)
Net changes in advances with consolidated entities	62,396	(20,040)	(21,121)
Net cash (used in) provided by financing activities-continuing operations	62,565	(23,099)	(23,741)
Net cash used in financing activities-discontinued operations	(30)	(390)	(190)
Net cash (used in) provided by financing activities	62,535	(23,489)	(23,931)
Net (decrease) increase in cash and cash equivalents	196	354	1,008
Cash and cash equivalents, beginning of period	1,850	1,496	488
Cash and cash equivalents, end of period	2,046	1,850	1,496
Consolidating Adjustments
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities-continuing operations	(186)	(774)	(547)
Net cash provided by (used in) operating activities	(186)	(774)	(547)
FINANCING ACTIVITIES:
Net changes in advances with consolidated entities	186	774	547
Net cash (used in) provided by financing activities-continuing operations	186	774	547
Net cash (used in) provided by financing activities	$ 186	$ 774	$ 547