NGL Energy Partners (NGL) 10-K 3 Jun 21 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Mar. 31, 2021	May 28, 2021	Sep. 30, 2020
Entity Information
Document Type	10-K
Document Annual Report	true
Document Period End Date	Mar. 31, 2021
Document Transition Report	false
Entity File Number	001-35172
Entity Registrant Name	NGL Energy Partners LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	27-3427920
Entity Address, Address Line One	6120 South Yale Avenue, 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
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Share Price			$ 3.96
Entity Public Float			$ 344,600,000
Entity Common Stock, Shares Outstanding		129,593,939
Entity Central Index Key	0001504461
Amendment Flag	false
Current Fiscal Year End Date	--03-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
NEW YORK STOCK EXCHANGE, INC. | Common units
Entity Information
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
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
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	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
CURRENT ASSETS:
Cash and cash equivalents	$ 4,829	$ 22,704
Accounts receivable-trade, net of allowance for expected credit losses of $2,192 and $4,540, respectively	725,943	566,834
Accounts receivable-affiliates	9,435	12,934
Inventories	158,467	69,634
Prepaid expenses and other current assets	109,164	101,981
Total current assets	1,007,838	774,087
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $776,279 and $529,068, respectively	2,706,853	2,851,555
PROPERTY, PLANT AND EQUIPMENT, accumulated depreciation	(776,279)	(529,068)
GOODWILL	744,439	993,587
INTANGIBLE ASSETS, net of accumulated amortization of $517,518 and $631,449, respectively	1,262,613	1,612,480
INTANGIBLE ASSETS, accumulated amortization	(517,518)	(631,449)
INVESTMENTS IN UNCONSOLIDATED ENTITIES	22,719	23,182
OPERATING LEASE RIGHT-OF-USE ASSETS	152,146	180,708
OTHER NONCURRENT ASSETS	50,733	63,137
Total assets	5,947,341	6,498,736
CURRENT LIABILITIES:
Accounts payable-trade	679,868	515,049
Accounts payable-affiliates	119	17,717
Accrued expenses and other payables	170,400	232,062
Advance payments received from customers	11,163	19,536
Current maturities of long-term debt	2,183	4,683
Operating lease obligations	47,070	56,776
Total current liabilities	910,803	845,823
LONG-TERM DEBT, net of debt issuance costs of $55,555 and $19,795, respectively, and current maturities	3,319,030	3,144,848
Debt issuance costs, noncurrent, net	(55,555)	(19,795)
OPERATING LEASE OBLIGATIONS	103,637	121,013
OTHER NONCURRENT LIABILITIES	114,615	114,079
COMMITMENTS AND CONTINGENCIES (NOTE 9)
EQUITY:
General partner, representing a 0.1% interest, 129,724 and 128,901 notional units, respectively	(52,189)	(51,390)
Limited partners, representing a 99.9% interest, 129,593,939 and 128,771,715 common units issued and outstanding, respectively	582,784	1,366,152
Accumulated other comprehensive loss	(266)	(385)
Noncontrolling interests	69,471	72,954
Total equity	948,159	1,735,690
Total liabilities and equity	$ 5,947,341	$ 6,498,736
General Partner
EQUITY:
General partner interest	0.10%
General partner, notional units outstanding (in units)	129,724	128,901
Limited Partner
EQUITY:
Limited partner interest	99.90%
Limited partners, common units issued and outstanding (in units)	129,593,939	128,771,715
Class D Preferred Units
CURRENT LIABILITIES:
PREFERRED UNITS	$ 551,097	$ 537,283
Preferred units dividend rate	9.00%
Temporary equity, issued and outstanding (in units)	600,000	600,000
Class B Perpetual Preferred Units
EQUITY:
Preferred limited partners	$ 305,468	$ 305,468
Preferred units, issued and outstanding (in units)	12,585,642	12,585,642
Class C Perpetual Preferred Units
EQUITY:
Preferred limited partners	$ 42,891	$ 42,891
Preferred units, issued and outstanding (in units)	1,800,000	1,800,000
Trade Accounts Receivable
CURRENT ASSETS:
Accounts receivable - trade, allowance for expected credit loss	$ 2,192	$ 4,540

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
REVENUES:
Water Solutions	$ 370,986	$ 422,059	$ 301,686
Crude Oil Logistics	1,721,636	2,549,767	3,136,635
Liquids Logistics	3,133,146	4,611,136	5,249,474
Other	1,255	1,038	1,362
Total Revenues	5,227,023	7,584,000	8,689,157
COST OF SALES:
Water Solutions	9,622	(33,870)	(10,787)
Crude Oil Logistics	1,515,993	2,293,953	2,902,656
Liquids Logistics	2,966,391	4,342,526	5,089,263
Other	1,816	1,774	1,929
Total Cost of Sales	4,493,822	6,604,383	7,983,061
OPERATING COSTS AND EXPENSES:
Operating	254,562	332,993	231,065
General and administrative	70,468	113,664	107,407
Depreciation and amortization	317,227	265,312	211,973
Loss on disposal or impairment of assets, net	475,436	261,786	34,296
Revaluation of liabilities	6,261	9,194	(5,373)
Operating (Loss) Income	(390,753)	(3,332)	126,728
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities	1,938	1,291	2,533
Interest expense	(198,799)	(181,184)	(164,725)
(Loss) gain on early extinguishment of liabilities, net	(16,692)	1,341	(12,340)
Other (expense) income, net	(36,503)	1,684	(30,418)
Loss From Continuing Operations Before Income Taxes	(640,809)	(180,200)	(78,222)
INCOME TAX BENEFIT (EXPENSE)	3,391	(345)	(1,233)
Loss From Continuing Operations	(637,418)	(180,545)	(79,455)
(Loss) Income From Discontinued Operations, net of Tax	(1,769)	(218,235)	418,850
Net (Loss) Income	(639,187)	(398,780)	339,395
LESS: NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	(632)	1,773	20,206
LESS: NET LOSS ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS	0	0	446
NET (LOSS) INCOME ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	(639,819)	(397,007)	360,047
NET LOSS FROM CONTINUING OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	(730,683)	(367,246)	(171,153)
NET (LOSS) INCOME FROM DISCONTINUED OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	(1,767)	(218,017)	418,877
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	$ (732,450)	$ (585,263)	$ 247,724
BASIC (LOSS) INCOME PER COMMON UNIT
Loss From Continuing Operations	$ (5.67)	$ (2.88)	$ (1.39)
(Loss) Income From Discontinued Operations, net of Tax	(0.01)	(1.71)	3.41
Net (Loss) Income	(5.68)	(4.59)	2.01
DILUTED (LOSS) INCOME PER COMMON UNIT
Loss From Continuing Operations	(5.67)	(2.88)	(1.39)
(Loss) Income From Discontinued Operations, net of Tax	(0.01)	(1.71)	3.41
Net (Loss) Income	$ (5.68)	$ (4.59)	$ 2.01
BASIC WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	128,980,823	127,411,908	123,017,064
DILUTED WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	128,980,823	127,411,908	123,017,064

Consolidated Statements of Comp

Consolidated Statements of Comprehensive (Loss) Income - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Statement of Comprehensive Income [Abstract]
Net (loss) income	$ (639,187)	$ (398,780)	$ 339,395
Other comprehensive income (loss)	119	(130)	(9)
Comprehensive (loss) income	$ (639,068)	$ (398,910)	$ 339,386

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Thousands	Total	Oaktree Capital Management L.P.Class A Convertible Preferred Units	Accumulated other comprehensive income (loss)	Noncontrolling interests	Preferred Class B and Class C Preferred Units	Preferred Class B and Class C Preferred UnitsPreferred Class B and Class C Preferred Units	General Partner	Class B Perpetual Preferred Units	Class B Perpetual Preferred UnitsClass B Perpetual Preferred Units	Limited Partner	Limited PartnerCommon units	Class C Perpetual Preferred Units	Class C Perpetual Preferred UnitsClass C Perpetual Preferred Units
Beginning Balance (in units) at Mar. 31, 2018									8,400,000		121,472,725
Beginning 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 18)	(854)			(791)						(63)
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)
Investment in NGL Energy Holdings LLC	0
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)	$ (67,200)								(67,239)
Net (loss) income	339,841			(20,206)			387			359,660
Other comprehensive income (loss)	(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
Beginning Balance (in units) at Mar. 31, 2018									8,400,000		121,472,725
Beginning Balance at Mar. 31, 2018	2,086,095		(1,815)	83,503			(50,819)	202,731		1,852,495
Increase (Decrease) in Partnership Capital
Units issued, net of offering costs (Note 10)							100
Ending Balance (in units) at Mar. 31, 2021						14,385,642					129,593,939
Ending Balance at Mar. 31, 2021	948,159		(266)	69,471	$ 348,359		(52,189)			582,784
Increase (Decrease) in Partnership Capital
Cumulative effect of new accounting principle in period of adoption | ASC 606	139,306						139			139,167
Cumulative effect of new accounting principle in period of adoption | Accounting Standards Update 2016-01	0		1,569				(2)			(1,567)
Beginning Balance (in units) at Mar. 31, 2019									8,400,000		124,508,497
Beginning Balance at Mar. 31, 2019	2,277,818		(255)	58,748			(50,603)	202,731		2,067,197
Increase (Decrease) in Partnership Capital
Distributions to general and common unit partners and preferred unitholders (Note 10)	(258,362)						(342)			(258,020)
Distributions to noncontrolling interest owners	(1,145)			(1,145)
Repurchase of warrants	0
Mesquite Disposals Unlimited, LLC ("Mesquite") acquisition	17,124			17,124
Investment in NGL Energy Holdings LLC	(15,226)									(15,226)
Equity issued pursuant to incentive compensation plan (in units)											2,938,481
Equity issued pursuant to incentive compensation plan (Note 10)	32,964						33			32,931
Common unit repurchases and cancellations (in units)											(133,634)
Common unit repurchases and cancellations (Note 10)	(1,644)									(1,644)
Warrants exercised (in units)											1,458,371
Warrants exercised (Note 10)	15									15
Accretion of beneficial conversion feature of Class A convertible preferred units (Note 10)	(36,517)	$ (36,500)								(36,517)
Class A convertible preferred units redemption - amount paid in excess of carrying value (Note 10)	(78,797)									(78,797)
Units issued, net of offering costs (in units)									4,185,642				1,800,000
Units issued, net of offering costs (Note 10)								$ 102,737				$ 42,891
Issuance of warrants, net of offering costs (Note 10)	52,742									52,742
Net (loss) income	(398,780)			(1,773)			(478)			(396,529)
Other comprehensive income (loss)	(130)		(130)
Ending Balance (in units) at Mar. 31, 2020						14,385,642					128,771,715
Ending Balance at Mar. 31, 2020	1,735,690		(385)	72,954	348,359		(51,390)			1,366,152
Increase (Decrease) in Partnership Capital
Distributions to general and common unit partners and preferred unitholders (Note 10)	(147,780)						(65)			(147,715)
Distributions to noncontrolling interest owners	(4,115)			(4,115)
Repurchase of warrants	0
Investment in NGL Energy Holdings LLC	0
Equity issued pursuant to incentive compensation plan (in units)											892,450
Equity issued pursuant to incentive compensation plan (Note 10)	4,727						0			4,727
Common unit repurchases and cancellations (in units)											(70,226)
Common unit repurchases and cancellations (Note 10)	(182)									(182)
Net (loss) income	(639,187)			632			(733)			(639,086)
Other comprehensive income (loss)	119		119
Ending Balance (in units) at Mar. 31, 2021						14,385,642					129,593,939
Ending Balance at Mar. 31, 2021	948,159		$ (266)	$ 69,471	$ 348,359		(52,189)			582,784
Increase (Decrease) in Partnership Capital
Cumulative effect of new accounting principle in period of adoption	$ (1,113)
Cumulative effect of new accounting principle in period of adoption | Accounting Standards Update 2016-13							$ (1)			$ (1,112)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
OPERATING ACTIVITIES:
Net (loss) income	$ (639,187)	$ (398,780)	$ 339,395
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Loss (income) from discontinued operations, net of tax	1,769	218,235	(418,850)
Depreciation and amortization, including amortization of debt issuance costs	331,200	276,848	221,674
Loss on early extinguishment or revaluation of liabilities, net	22,953	7,853	6,967
Non-cash equity-based compensation expense	6,727	26,510	41,367
Loss on disposal or impairment of assets, net	475,436	261,786	34,296
Provision for expected credit losses	5,988	1,002	381
Net adjustments to fair value of commodity derivatives	83,578	(85,941)	(10,817)
Equity in earnings of unconsolidated entities	(1,938)	(1,291)	(2,533)
Distributions of earnings from unconsolidated entities	3,364	0	2,206
Lower of cost or net realizable value adjustments	3,898	33,973	14,305
Other	1,513	2,541	(485)
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable-trade and affiliates	(162,031)	436,349	(185,717)
Inventories	(92,731)	29,779	(10,093)
Other current and noncurrent assets	92,555	14,081	43,996
Accounts payable-trade and affiliates	207,505	(375,257)	87,739
Other current and noncurrent liabilities	(34,836)	(65,262)	(12,308)
Net cash provided by operating activities-continuing operations	305,763	382,426	151,523
Net cash (used in) provided by operating activities-discontinued operations	(1,769)	81,629	185,727
Net cash provided by operating activities	303,994	464,055	337,250
INVESTING ACTIVITIES:
Capital expenditures	(186,801)	(555,713)	(455,586)
Acquisitions, net of cash acquired	901	(1,268,474)	(300,614)
Net settlements of commodity derivatives	(80,372)	86,702	(10,173)
Proceeds from sales of assets	45,742	17,621	16,177
Proceeds from divestitures of businesses and investments, net	0	0	335,809
Investments in unconsolidated entities	(963)	(21,218)	(389)
Distributions of capital from unconsolidated entities	0	440	1,440
Repayments on loan for natural gas liquids facility	0	3,022	10,336
Loan to affiliate	0	0	(1,515)
Net cash used in investing activities-continuing operations	(221,493)	(1,737,620)	(404,515)
Net cash provided by investing activities-discontinued operations	0	298,864	857,988
Net cash (used in) provided by investing activities	(221,493)	(1,438,756)	453,473
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,261,000	4,074,000	4,098,500
Payments on revolving credit facilities	(2,727,000)	(3,775,000)	(3,897,000)
Issuance of senior secured and unsecured notes and term credit agreement	2,300,000	700,000	0
Repayment of term credit agreements	(555,562)	0	0
Repayment and repurchase of senior unsecured notes	(115,796)	(454)	(737,058)
Proceeds from borrowings on other long-term debt	50,000	0	0
Payments on other long-term debt	(5,590)	(653)	(653)
Debt issuance costs	(65,566)	(14,950)	(1,383)
Contributions from noncontrolling interest owners, net	0	0	169
Distributions to general and common unit partners and preferred unitholders	(142,128)	(244,400)	(236,633)
Distributions to noncontrolling interest owners	(4,115)	(1,145)	0
Proceeds from sale of preferred units, net of offering costs	0	622,391	0
Payments for redemption of preferred units	0	(265,128)	0
Repurchase of warrants	0	0	(14,988)
Common unit repurchases and cancellations	(182)	(1,644)	(297)
Payments for settlement and early extinguishment of liabilities	(95,437)	(98,958)	(4,577)
Investment in NGL Energy Holdings LLC	0	(15,226)	0
Net cash (used in) provided by financing activities-continuing operations	(100,376)	978,833	(793,920)
Net cash used in financing activities-discontinued operations	0	0	(325)
Net cash (used in) provided by financing activities	(100,376)	978,833	(794,245)
Net (decrease) increase in cash and cash equivalents	(17,875)	4,132	(3,522)
Cash and cash equivalents, beginning of period	22,704	18,572	22,094
Cash and cash equivalents, end of period	4,829	22,704	18,572
Supplemental cash flow information:
Cash interest paid	168,642	155,445	170,632
Income taxes paid (net of income tax refunds)	2,586	4,931	2,423
Supplemental non-cash investing and financing activities:
Distributions declared but not paid to Class B, Class C and Class D preferred unitholders	13,814	18,687	4,725
Accrued capital expenditures	$ 21,824	$ 88,917	$ 19,121

Nature of Operations and Organi

Nature of Operations and Organization	12 Months Ended
	Mar. 31, 2021
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, 2021, our operations included three segments: • Our Water Solutions segment transports, treats, recycles and disposes of produced and flowback water generated from oil and natural gas production. We also sell produced water for reuse and brackish non-potable water to our producer customers to be used in their crude oil exploration and production activities. As part of processing water, we aggregate and sell recovered crude oil, also known as skim oil. We also dispose of solids such as tank bottoms, drilling fluids and drilling muds and perform other ancillary services such as truck and frac tank washouts. Our activities in this segment are underpinned by long-term, fixed fee contracts and acreage dedications, some of which contain minimum volume commitments, with leading oil and gas companies including large, investment grade producer customers. • 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 and transportation services through its owned assets. Our activities in this segment are supported by certain long-term, fixed rate contracts which include minimum volume commitments on our pipelines. • Our Liquids Logistics segment (formerly named Liquids and Refined Products) conducts supply operations for natural gas liquids, refined petroleum products and biodiesel to a broad range of commercial, retail and industrial customers across the United States and Canada. These operations are conducted through our 28 company-owned terminals, third-party storage and terminal facilities, common carrier pipelines and a fleet of leased railcars. We also provide marine exports of butane through our facility located in Chesapeake, Virginia.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Mar. 31, 2021
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 either cost of sales or operating expense. 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 2017 to 2020 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. We have a deferred tax liability of $45.8 million and $56.4 million at March 31, 2021 and 2020, respectively, as a result of acquiring corporations in connection with certain of our acquisitions (see Note 4), which is included within other noncurrent liabilities in our consolidated balance sheets. 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 during the year ended March 31, 2021 was $4.7 million with an effective tax rate of 39.7%. The deferred tax benefit recorded during the year ended March 31, 2020 was $2.9 million with an effective tax rate of 27.8%. 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, 2021 or 2020. 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. See Note 17 for a further discussion of our allowance for expected credit losses. 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. We did not have any customers that represented over 10% of consolidated revenues for fiscal years 2021, 2020 and 2019. 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, 2021 2020 (in thousands) Crude oil $ 64,916 $ 18,201 Propane 45,521 25,163 Butane 19,189 9,619 Biodiesel 16,169 8,195 Ethanol 3,056 1,834 Diesel 2,252 2,414 Other 7,364 4,208 Total $ 158,467 $ 69,634 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. At March 31, 2021, cumulative equity earnings and cumulative distributions of our unconsolidated entities since they were acquired were $5.1 million and $6.8 million, respectively. Our investments in unconsolidated entities consist of the following at the dates indicated: Ownership March 31, Entity Segment Interest (1) Date Acquired 2021 2020 (in thousands) Water services and land company Water Solutions 50% November 2019 $ 15,832 $ 16,607 Water services and land company Water Solutions 50% November 2019 2,284 2,092 Water services and land company Water Solutions 10% November 2019 3,254 3,384 Aircraft company (2) Corporate and Other 50% June 2019 748 447 Water services company Water Solutions 50% August 2018 424 449 Natural gas liquids terminal company Liquids Logistics 50% March 2019 177 203 Total $ 22,719 $ 23,182 (1) Ownership interest percentages are at March 31, 2021. (2) This is an investment with a related party. See Note 13 for a further discussion. Other Noncurrent Assets Other noncurrent assets consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) Loan receivable (1) $ 2,962 $ 5,374 Line fill (2) 28,110 25,763 Minimum shipping fees - pipeline commitments (3) 13,171 17,443 Other 6,490 14,557 Total $ 50,733 $ 63,137 (1) Amounts at March 31, 2021 and 2020 represent the noncurrent portion of a loan receivable, net of an allowance for an expected credit loss, with a former related party. In addition, the amount at March 31, 2020 represents the noncurrent portion of a loan receivable associated with our interest in the construction of a natural gas liquids loading/unloading facility (the “Facility”) that is utilized by a third party. The third party filed for Chapter 11 bankruptcy in July 2019. For a further discussion, see Note 18. (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, 2021, line fill consisted of 423,978 barrels of crude oil. At March 31, 2020, line fill consisted of 335,069 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). During the three months ended March 31, 2020, we recorded an impairment of $7.7 million primarily due to adjusting the cost basis of pipeline line fill to the market price of propane as of March 31, 2020. (3) Represents the noncurrent portion of minimum shipping fees paid in excess of volumes shipped, or deficiency credits, for one contract with a crude oil pipeline operator. This amount can be recovered when volumes shipped exceed the minimum monthly volume commitment (see Note 9). As of March 31, 2021, the deficiency credit was $17.4 million, of which $4.2 million is recorded within prepaid expenses and other current assets in our consolidated balance sheet. Accrued Expenses and Other Payables Accrued expenses and other payables consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) Accrued interest $ 56,299 $ 39,803 Accrued compensation and benefits 41,456 29,990 Derivative liabilities 21,562 17,777 Excise and other tax liabilities 10,970 9,941 Contingent consideration liability (1) 3,083 102,419 Product exchange liabilities 1,188 1,687 Other 35,842 30,445 Total $ 170,400 $ 232,062 (1) Decrease is due to the monthly installment payments totaling $100.0 million made during the year ended March 31, 2021 related to our acquisition of certain assets of Mesquite. We made our last installment payment in December 2020. 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 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 Facility (as defined herein), ABL Facility (as defined herein) and the Sawtooth Caverns, LLC (“Sawtooth”) credit agreement. 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, 2021 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. 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. 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 and 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. Also, as discussed in Note 4, we made certain adjustments during the year ended March 31, 2021 to our estimates of the acquisition date fair values of the assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2020. Recent Accounting Pronouncements In November 2020, the Securities and Exchange Commission (“SEC”) issued a Final Rule, “Management’s Discussion and Analysis, Selected Financial Data, and Supplementary Financial Information”, to modernize, simplify and enhance certain financial disclosure requirements in Regulation S-K. The Final Rule eliminates Regulation S-K, Item 301. Selected Financial Data, streamlines the requirements in Item 302. Supplementary Financial Information, and updates certain requirements in Item 303. Management’s Discussion and Analysis of Financial Condition and Results of Operations. The guidance is effective for fiscal periods ending on or after August 9, 2021, although early adoption is permitted if an entity complies with an amended Item in its entirety. Effective March 31, 2021, we adopted a portion of this guidance by electing to comply with guidance related to Item 301, which eliminated the Selected Financial Data, and Item 302, which allowed us to eliminate the Quarterly Financial Data from this filing. In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity.” This ASU (i) simplifies an issuer’s accounting for convertible instruments by eliminating two of the three models in ASC 470-20 that require separate accounting for embedded conversion features, (ii) amends diluted earnings per share calculations for convertible instruments by requiring the use of the if-converted method and (iii) simplifies the settlement assessment entities are required to perform on contracts that can potentially settle in an entity’s own equity by removing certain requirements. This guidance is effective for interim and annual periods beginning after December 15, 2021, with early adoption permitted. We are currently evaluating the effect that this guidance will have on our financial position, results of operations and cash flows. In March 2020, the SEC issued “Financial Disclosures About Guarantors and Issuers of Guaranteed Securities and Affiliates Whose Securities Collateralize a Registrant’s Securities”, which amends the disclosure requirements for guarantors and issuers of guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X. The amendment simplifies the disclosure requirements and permits the amended disclosures to be provided outside the footnotes in audited annual or unaudited interim consolidated financial statements in all filings. The guidance is effective for the Partnership for fiscal periods ending after January 4, 2021, although early adoption is permitted. We adopted this guidance effective April 1, 2020 and elected to include the required summarized financial information in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations –Liquidity, Sources of Capital and Capital Resource Activities– Guarantor Summarized Financial Information .” In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” The ASU provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. This guidance is effective prospectively upon issuance through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of this ASU. We are currently evaluating the effect that this guidance will have on our financial position, results of operations and cash flows. In June 2016, the FASB issued 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 trade 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. We adopted ASU No. 2016-13 on April 1, 2020, using the modified retrospective approach with a cumulative effect adjustment of $1.1 million to opening equity at the beginning of the period of adoption. See Note 17 for a further discussion of the impact of the adoption of this ASU on our consolidated financial statements.

(Loss) Income Per Common Unit

(Loss) Income Per Common Unit	12 Months Ended
	Mar. 31, 2021
Earnings Per Unit [Abstract]
(Loss) Income Per Common Unit	(Loss) Income 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, 2021 2020 2019 Weighted average common units outstanding during the period: Common units - Basic 128,980,823 127,411,908 123,017,064 Common units - Diluted 128,980,823 127,411,908 123,017,064 For the years ended March 31, 2021, 2020 and 2019, all potential common units or convertible securities were considered antidilutive. Our (loss) income per common unit is as follows for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands, except unit and per unit amounts) Loss from continuing operations $ (637,418) $ (180,545) $ (79,455) Less: Continuing operations (income) loss attributable to noncontrolling interests (632) 1,773 20,206 Net loss from continuing operations attributable to NGL Energy Partners LP (638,050) (178,772) (59,249) Less: Distributions to preferred unitholders (1)(2) (93,364) (188,734) (111,936) Less: Continuing operations net loss allocated to general partner (3) 731 260 32 Net loss from continuing operations allocated to common unitholders $ (730,683) $ (367,246) $ (171,153) (Loss) income from discontinued operations, net of tax $ (1,769) $ (218,235) $ 418,850 Less: Discontinued operations loss attributable to redeemable noncontrolling interests — — 446 Less: Discontinued operations net loss (income) allocated to general partner (3) 2 218 (419) Net (loss) income from discontinued operations allocated to common unitholders $ (1,767) $ (218,017) $ 418,877 Net (loss) income allocated to common unitholders $ (732,450) $ (585,263) $ 247,724 Basic (loss) income per common unit Loss from continuing operations $ (5.67) $ (2.88) $ (1.39) (Loss) income from discontinued operations, net of tax $ (0.01) $ (1.71) $ 3.41 Net (loss) income $ (5.68) $ (4.59) $ 2.01 Diluted (loss) income per common unit Loss from continuing operations $ (5.67) $ (2.88) $ (1.39) (Loss) income from discontinued operations, net of tax $ (0.01) $ (1.71) $ 3.41 Net (loss) income $ (5.68) $ (4.59) $ 2.01 Basic weighted average common units outstanding 128,980,823 127,411,908 123,017,064 Diluted weighted average common units outstanding 128,980,823 127,411,908 123,017,064 (1) This amount includes distributions to preferred unitholders. The final accretion for the beneficial conversion of the 10.75% Class A Preferred Units (as defined herein) and the excess of the 10.75% Class A Preferred Units repurchase price over the carrying value of the units, as discussed further in Note 10, are included in the year ended March 31, 2020. (2) Includes cumulative dividends for the quarter ended March 31, 2021 which were earning but not declared or paid (see Note 10). (3) Net loss (income) allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights.

Acquisitions

Acquisitions	12 Months Ended
	Mar. 31, 2021
Business Combinations [Abstract]
Acquisitions	Acquisitions The following summarizes our acquisitions of assets during the year ended March 31, 2021: In March 2021, we acquired the Ambassador pipeline, an approximately 225-mile natural gas liquids pipeline, which runs from the Kalkaska gas plant in Kalkaska County, Michigan to a termination point near Marysville in St. Clair County, Michigan. This pipeline complements our existing assets in the upper Midwest and expands our presence with anchor assets in the state of Michigan, one of the top propane markets in the United States. Total consideration for this acquisition was $18.2 million, which we are accounting for as an acquisition of assets. The consideration paid for this transaction was allocated primarily to property, plant and equipment. This acquisition is included in our Liquids Logistics segment. The following summarizes the status of the preliminary purchase price allocation of acquisitions completed prior to April 1, 2020: Hillstone Environmental Partners, LLC (“Hillstone”) Acquisition As of October 31, 2020, we completed the acquisition accounting for the Hillstone acquisition. During the seven months ended October 31, 2020, we received additional information and recorded a decrease of $0.7 million to current assets, a decrease of $5.1 million to current liabilities and a decrease of $6.0 million to the deferred tax liability with the offset to goodwill. Also, there was a $0.9 million decrease to the preliminary purchase price as a result of a true up to the working capital acquired. This amount was recorded as an offset to goodwill. There were no other adjustments to the fair value of assets acquired and liabilities assumed during the seven months ended October 31, 2020.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Mar. 31, 2021
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 2021 2020 (in years) (in thousands) Natural gas liquids terminal and storage assets 2 - 30 $ 319,554 $ 314,694 Pipeline and related facilities 30 - 40 264,405 244,751 Vehicles and railcars 3 - 25 126,088 123,937 Water treatment facilities and equipment 3 - 30 1,930,437 1,525,859 Crude oil tanks and related equipment 2 - 30 238,924 234,143 Barges and towboats 5 - 30 137,386 125,162 Information technology equipment 3 - 7 50,220 34,261 Buildings and leasehold improvements 3 - 40 165,679 151,690 Land 100,352 91,446 Tank bottoms and line fill (1) 20,237 20,346 Other 3 - 20 15,054 14,627 Construction in progress 114,796 499,707 3,483,132 3,380,623 Accumulated depreciation (776,279) (529,068) Net property, plant and equipment $ 2,706,853 $ 2,851,555 (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. The following table summarizes depreciation expense and capitalized interest expense for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands) Depreciation expense $ 190,204 $ 132,791 $ 101,515 Capitalized interest expense $ 2,778 $ 650 $ 482 Amounts in the table above do not include depreciation expense and capitalized interest related to TransMontaigne Product Services, LLC (“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 19). We record (gains) losses from the sales of property, plant and equipment and any write-downs in value due to impairment within loss 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, 2021 2020 2019 (in thousands) Water Solutions $ 36,492 $ 22,491 $ 3,067 Crude Oil Logistics 1,766 36 3,489 Liquids Logistics 3,350 (30) 993 Corporate 228 — — Total $ 41,836 $ 22,497 $ 7,549 During the year ended March 31, 2021, the following transactions were recorded within our Water Solutions segment: • An impairment charge of $30.6 million to write down the value of an asset group due to a decline in producer activity, resulting in lower disposal volumes. See Note 7 for a discussion of the impairment of intangible assets within this asset group. • An impairment charge of $11.9 million to write down the value of certain inactive saltwater disposal facilities that we do not expect to bring back online. • A net loss of $6.7 million related to write-down or write off of certain assets, including facilities damaged by lightning strikes and abandoned projects, and the sale of certain other miscellaneous assets. • A gain of $12.8 million related to the sale of certain permits, land and a saltwater disposal facility (see Note 18). During the year ended March 31, 2020, the following transactions were recorded within our Water Solutions segment: • An impairment charge of $13.5 million to write down the value of certain inactive saltwater disposal facilities. • A net loss of $9.0 million related to write-down or write off of certain assets, including abandoned projects, and the sale of certain other miscellaneous assets.

Goodwill

Goodwill	12 Months Ended
	Mar. 31, 2021
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The following table summarizes changes in goodwill by segment for the periods indicated (in thousands): Water Crude Oil Liquids Logistics Total (in thousands) Balances at March 31, 2019 $ 410,139 $ 579,846 $ 120,471 $ 1,110,456 Revisions to acquisition accounting 4,755 — (2,103) 2,652 Acquisitions 129,764 — 715 130,479 Impairment (250,000) — — (250,000) Balances at March 31, 2020 294,658 579,846 119,083 993,587 Revisions to acquisition accounting (Note 4) (11,348) — — (11,348) Impairment — (237,800) — (237,800) Balances at March 31, 2021 $ 283,310 $ 342,046 $ 119,083 $ 744,439 Fiscal Year 2021 Goodwill Impairment Assessment We performed a qualitative assessment as of January 1, 2021 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 our reporting units was more likely than not greater than the carrying value of the reporting units as of January 1, 2021, with the exception of our Water Solutions reporting unit, and our Crude Oil Logistics reporting unit, which was tested for impairment as of December 31, 2020. See below for a further discussion of the testing. Due to lower than expected disposal volumes as a result of a slower than expected recovery in oil production in the various basins in which our Water Solutions reporting unit operates and the completion of our annual budget process, it was decided that the goodwill within the Water Solutions reporting units should be tested for impairment as of January 1, 2021. We estimated the fair value of our Water Solutions 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 the Water Solutions 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) the crude oil price environment as reflected in crude oil forward prices as of the test date, (ii) disposal volumes based on historical information and estimates of future drilling and completion activity, as well as expectations for future demand recovery and (iii) estimated fixed and variable costs. The discounted cash flows for the Water Solutions reporting unit were based on five years of projected cash flows and we applied a discount rate and terminal multiple that we believe would be applied by a theoretical market participant in similar market transactions. Based on this test, we concluded that the fair value of the Water Solutions reporting unit exceeded its carrying value by approximately 3.0%. As discussed in Note 18, in December 2020, we reached a settlement in the Extraction Oil & Gas, Inc.(“Extraction”) bankruptcy case, which is expected to result in decreases in future cash flows for certain of our assets. Based on this aforementioned event, we concluded that a triggering event occurred, which required us to perform a quantitative impairment test as of December 31, 2020 for our Crude Oil Logistics reporting unit. We estimated the fair value of the Crude Oil Logistics 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 the Crude Oil Logistics 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) the crude oil price environment as reflected in crude oil forward prices as of the test date, (ii) volumes based on historical information and estimates of future drilling and completion activity, as well as expectations for future demand recovery and (iii) estimated fixed and variable costs. The discounted cash flows for the Crude Oil Logistics reporting unit were based on five years of projected cash flows and we applied a discount rate and terminal multiple that we believe would be applied by a theoretical market participant in similar market transactions. Based on this test, we concluded that the fair value of the Crude Oil Logistics reporting unit was less than its carrying value by approximately 17.0%. During the three months ended December 31, 2020, in our Crude Oil Logistics reporting unit, we recorded a goodwill impairment charge of $237.8 million within loss on disposal or impairment of assets, net in our consolidated statement of operations. Fiscal Year 2020 Goodwill Impairment Assessment We performed a qualitative assessment as of January 1, 2020 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 as of January 1, 2020. During the month of March 2020, our market capitalization declined significantly driven by current macroeconomic conditions including the collapse of oil prices driven by both the decrease in demand caused by the novel strain of coronavirus (COVID-19) pandemic and excess supply, as well as changing market conditions and expected lower crude oil production in certain regions, resulting in expected decreases in future cash flows for certain of our assets. In addition, the uncertainty related to oil demand continues to have a significant impact on the investment and operating plans of our primary customers. Based on these events, we concluded that a triggering event occurred which required us to perform a quantitative impairment test as of March 31, 2020 for our reporting units. We estimated the fair value of our reporting units 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 reporting units 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) the crude oil price environment as reflected in crude oil forward prices as of the test date, (ii) volumes based on historical information and estimates of future drilling and completion activity, as well as expectations for future demand recovery and (iii) estimated fixed and variable costs. The discounted cash flows for each reporting unit were based on five years of projected cash flows and we applied discount rates and terminal multiples that we believe would be applied by a theoretical market participant in similar market transactions. Based on these tests, we concluded that the fair values of each of our reporting units exceeded their carrying values with the exception of our Water Solutions reporting unit, whose fair value was less than its carrying value by 7.3%. During the three months ended March 31, 2020, in our Water Solutions reporting unit, we recorded a goodwill impairment charge of $250.0 million within loss on disposal or impairment of assets, net in our consolidated statement of operations. 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 Logistics 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 18). 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 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.

Intangible Assets

Intangible Assets	12 Months Ended
	Mar. 31, 2021
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets Our intangible assets consist of the following at the dates indicated: March 31, 2021 March 31, 2020 Description Amortizable Lives Gross Carrying Accumulated Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 1,318,638 $ (450,639) $ 867,999 $ 1,435,573 $ (445,250) $ 990,323 Customer commitments 10 - 25 192,000 (13,440) 178,560 502,000 (111,677) 390,323 Pipeline capacity rights 30 7,799 (1,907) 5,892 7,799 (1,647) 6,152 Rights-of-way and easements 1 - 45 90,703 (9,270) 81,433 89,476 (6,506) 82,970 Water rights 13 - 30 100,369 (14,454) 85,915 100,937 (8,441) 92,496 Executory contracts and other agreements 5 - 30 48,709 (21,300) 27,409 48,570 (18,210) 30,360 Non-compete agreements 2 - 24 12,100 (6,102) 5,998 12,723 (4,735) 7,988 Debt issuance costs (1) 2 - 5 9,558 (406) 9,152 44,051 (34,983) 9,068 Total amortizable 1,779,876 (517,518) 1,262,358 2,241,129 (631,449) 1,609,680 Non-amortizable: Trade names 255 — 255 2,800 — 2,800 Total $ 1,780,131 $ (517,518) $ 1,262,613 $ 2,243,929 $ (631,449) $ 1,612,480 (1) Includes debt issuance costs related to the ABL Facility (as defined herein), Revolving Credit Facility (as defined herein) and the Sawtooth credit agreement. Debt issuance costs related to fixed-rate notes, Bridge Term Credit Agreement (as defined herein) and Term Credit Agreement (as defined herein) are reported as a reduction of the carrying amount of long-term debt. The weighted-average remaining amortization period for intangible assets is approximately 20.7 years. Write off of Intangible Assets During the year ended March 31, 2021, we recorded the following: • An impairment charge of $145.8 million against the customer commitment intangible asset related to a transportation contract with Extraction that was rejected as part of Extraction’s bankruptcy. See Note 18 for a further discussion of Extraction’s bankruptcy and the impairment of the intangible asset. • An impairment charge of $39.2 million to write down the value of a customer relationship intangible asset as part of the write down in value of a larger asset group (see Note 5). • A $4.5 million write off of the debt issuance costs related to the Revolving Credit Facility which was repaid and terminated on February 4, 2021 (see Note 8). • An impairment charge of $2.5 million to write down the value of the trade name as part of the write down of a larger asset group (see Note 5). Amortization expense is as follows for the periods indicated: Year Ended March 31, Recorded In 2021 2020 2019 (in thousands) Depreciation and amortization $ 127,023 $ 132,521 $ 110,458 Cost of sales 307 349 486 Interest expense 5,572 5,462 4,928 Operating expenses 247 286 — Total $ 133,149 $ 138,618 $ 115,872 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 19). Expected amortization of our intangible assets is as follows (in thousands): Year Ending March 31, 2022 $ 96,206 2023 78,510 2024 72,308 2025 67,807 2026 66,413 Thereafter 881,114 Total $ 1,262,358

Long-Term Debt

Long-Term Debt	12 Months Ended
	Mar. 31, 2021
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Our long-term debt consists of the following at the dates indicated: March 31, 2021 March 31, 2020 Face Unamortized Book Face Unamortized Book (in thousands) Senior secured notes: 7.500% Notes due 2026 (“2026 Senior Secured Notes”) $ 2,050,000 $ (44,246) $ 2,005,754 $ — $ — $ — Asset-based revolving credit facility 4,000 — 4,000 — — — Senior unsecured notes: 7.500% Notes due 2023 (“2023 Notes”) 555,251 (3,564) 551,687 607,323 (5,405) 601,918 6.125% Notes due 2025 (“2025 Notes”) 380,020 (3,297) 376,723 387,320 (4,217) 383,103 7.500% Notes due 2026 (“2026 Notes”) 338,402 (4,378) 334,024 450,000 (6,975) 443,025 Revolving credit facility: Expansion capital borrowings — — — 1,120,000 — 1,120,000 Working capital borrowings — — — 350,000 — 350,000 Bridge term credit agreement — — — 250,000 (3,198) 246,802 Other long-term debt 49,095 (70) 49,025 4,683 — 4,683 3,376,768 (55,555) 3,321,213 3,169,326 (19,795) 3,149,531 Less: Current maturities 2,183 — 2,183 4,683 — 4,683 Long-term debt $ 3,374,585 $ (55,555) $ 3,319,030 $ 3,164,643 $ (19,795) $ 3,144,848 (1) Debt issuance costs related to the ABL Facility, the Sawtooth credit agreement (included in other long-term debt) and the Revolving Credit Facility are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt. Recent Developments On February 4, 2021, we closed on our private offering of $2.05 billion of 7.5% 2026 Senior Secured Notes and a new credit agreement (the “New Credit Agreement”) which consists of a $500.0 million asset-based revolving credit facility (“ABL Facility”). Total offering costs and expenses were approximately $150.7 million, which includes certain make-whole (see Term Credit Agreement below) and consent costs (see Note 13). We used the net proceeds from the issuance of the 2026 Senior Secured Notes (along with borrowings under the ABL Facility) to (i) repay all outstanding borrowings under and terminate our existing revolving credit facility, (ii) repay all outstanding borrowings under and terminate our term credit agreement and (iii) pay fees and expenses in connection therewith as well as fees and expenses in connection with the issuance of the 2026 Senior Secured Notes and entering into the ABL Facility. 2026 Senior Secured Notes The 2026 Senior Secured Notes bear interest at 7.5%, which is payable on February 1 and August 1 of each year, beginning on August 1, 2021. The 2026 Senior Secured Notes mature on February 1, 2026. The 2026 Senior Secured Notes were issued pursuant to an indenture dated February 4, 2021 (the “Indenture”). The 2026 Senior Secured Notes are secured by first priority liens in substantially all of our assets other than our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets and second priority liens in our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets. The Indenture contains covenants that, among other things, limit our ability to: pay distributions or make other restricted payments or repurchase stock; incur or guarantee additional indebtedness or issue disqualified stock or certain preferred stock; make certain investments; create or incur liens; sell assets; enter into restrictions affecting the ability of restricted subsidiaries to make distributions, make loans or advances or transfer assets to the guarantors (including the Partnership); enter into certain transactions with our affiliates; designate restricted subsidiaries as unrestricted subsidiaries; and merge, consolidate or transfer or sell all or substantially all of our assets. The Indenture specifically restricts our ability to pay distributions until our total leverage ratio (as defined in the Indenture) for the most recently ended four full fiscal quarters at the time of the distribution is not greater than 4.75 to 1.00. These covenants are subject to a number of important exceptions and qualifications. We have an option to redeem all or a portion of the 2026 Senior Secured Notes at any time on or after February 1, 2023 at fixed redemption prices contained within the Indenture. Prior to such time, we, at our option, may redeem up to 40% of the aggregate principal amount of the 2026 Senior Secured Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at the redemption price specified in the Indenture. In addition, before February 1, 2023, we may redeem some or all of the 2026 Senior Secured Notes at a redemption price equal to 100% of the aggregate principal amount of the 2026 Senior Secured Notes redeemed, plus the applicable premium as specified in the Indenture and accrued and unpaid interest, if any, to, but not including, the redemption date. If we experience certain kinds of change of control triggering events, we will be required to offer to repurchase the 2026 Senior Secured Notes at 101% of the aggregate principal amount of the 2026 Senior Secured Notes repurchased plus accrued and unpaid interest on the 2026 Senior Secured Notes repurchased to, but not including, the date of purchase. Compliance At March 31, 2021, we were in compliance with the covenants under the 2026 Senior Secured Notes indenture. ABL Facility The $500.0 million ABL Facility is subject to a borrowing base, which includes a sub-limit for letters of credit. The initial borrowing base is $500.0 million and the sub-limit for letters of credit is $200.0 million. The ABL Facility is secured by a lien on substantially all of our assets, including among other things, a first priority lien on our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets and a second priority lien on all of our other assets. At March 31, 2021, $4.0 million had been borrowed under the ABL Facility and we had letters of credit outstanding of approximately $156.0 million. The ABL Facility is scheduled to mature at the earliest of (a) February 4, 2026 or (b) 91 days prior to the earliest maturity date in respect to any of our indebtedness in an aggregate principal amount of $50.0 million or greater, if such indebtedness is outstanding at such time, subject to certain exceptions. The ABL Facility bears interest at a LIBOR-based rate (with such customary provisions under the ABL Facility providing for the replacement of LIBOR with any successor rate) or an alternate base rate, in each case plus an applicable borrowing margin based on our Fixed Charge Coverage Ratio (as defined in the New Credit Agreement). The applicable margin for alternate base rate loans varies from 1.50% to 2.00% and the applicable margin for LIBOR-based loans varies from 2.50% to 3.00%. In addition, a commitment fee will be charged and payable quarterly in arrears based on the average daily unused portion of the revolving commitments under the ABL Facility. Such commitment fee will be 0.50% per year, subject to a reduction to 0.375% in the event our Fixed Charge Coverage Ratio is greater than or equal to 1.75 to 1.00. At March 31, 2021, the borrowings under the ABL Facility had a weighted average interest rate of 5.25% calculated as the prime rate of 3.25% plus a margin of 2.00% on the alternate base rate borrowings. On March 31, 2021, the interest rate in effect on letters of credit was 3.00%. The New Credit Agreement contains various affirmative and negative covenants, including financial reporting requirements and limitations on indebtedness, liens, mergers, consolidations, liquidations and dissolutions, sales of assets, distributions and other restricted payments, investments (including acquisitions) and transactions with affiliates. The New Credit Agreement contains, as the only financial covenant, a minimum Fixed Charge Coverage Ratio financial covenant that is tested based on the financial statements for the most recently ended fiscal quarter upon the occurrence and during the continuation of a Cash Dominion Event (as defined in the New Credit Agreement). At March 31, 2021, no Cash Dominion Event had occurred or was continuing. At March 31, 2021, we were in compliance with the covenants under the ABL Facility. 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 ABL 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 (“2019 Notes”). 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 (“2021 Notes”). The 2021 Notes were redeemed on October 16, 2018. See further discussion below. On October 24, 2016, we issued $700.0 million of 7.5% 2023 Notes. Interest is payable on May 1 and November 1 of each year. The 2023 Notes mature on November 1, 2023. On February 22, 2017, we issued $500.0 million of 6.125% 2025 Notes. Interest is payable on March 1 and September 1 of each year. The 2025 Notes mature on March 1, 2025. On April 9, 2019, we issued $450.0 million of 7.5% 2026 Notes in a private placement. Interest is payable on April 15 and October 15 of each year. The 2026 Notes mature on April 15, 2026. 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, 2021 2020 2019 (in thousands) 2019 Notes Notes repurchased $ — $ — $ 25,419 Cash paid (excluding payments of accrued interest) $ — $ — $ 25,406 Loss on early extinguishment of debt (1) $ — $ — $ (34) 2023 Notes Notes repurchased $ 52,072 $ — $ 8,624 Cash paid (excluding payments of accrued interest) $ 33,566 $ — $ 8,575 Gain (loss) on early extinguishment of debt (2) $ 18,096 $ — $ (63) 2025 Notes Notes repurchased $ 7,300 $ 1,815 $ — Cash paid (excluding payments of accrued interest) $ 3,647 $ 454 $ — Gain on early extinguishment of debt (3) $ 3,575 $ 1,341 $ — 2026 Notes Notes repurchased $ 111,598 $ — $ — Cash paid (excluding payments of accrued interest) $ 78,583 $ — $ — Gain on early extinguishment of debt (4) $ 31,463 $ — $ — (1) Loss on 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 less than $0.1 million. The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) Gain (loss) on early extinguishment of debt for the 2023 Notes during the years ended March 31, 2021 and 2019 is inclusive of the write off of debt issuance costs of $0.4 million and $0.1 million, respectively. The gain (loss) is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statements of operations. (3) Gain on early extinguishment of debt for the 2025 Notes during the years ended March 31, 2021 and 2020 is inclusive of the write off of debt issuance costs of $0.1 million and less than $0.1 million, respectively. The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statements of operations. (4) Gain on early extinguishment of debt for the 2026 Notes during the year ended March 31, 2021 is inclusive of the write off of debt issuance costs of $1.6 million. The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Compliance At March 31, 2021, we were in compliance with the covenants under all of the Senior Unsecured Notes indentures. Credit Agreement We were party to a credit agreement (“Credit Agreement”) with a syndicate of banks. The Credit Agreement provided up to $1.915 billion in aggregate commitments and consisted of a revolving credit facility to fund working capital needs, which had a capacity of $350.0 million 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 $1.565 billion (the “Expansion Capital Facility,” and together with the Working Capital Facility, the “Revolving Credit Facility”). On February 4, 2021, we repaid all of the outstanding borrowings under and terminated the Credit Agreement which included $0.3 million of termination expenses as well as the write off of debt issuance cost which were recorded within intangible assets (see Note 7). Term Credit Agreement On June 3, 2020, we entered into a new $250.0 million term credit agreement (the “Term Credit Agreement”) with certain funds and accounts managed by affiliates of Apollo Global Management, Inc. to refinance the previous Bridge Term Credit Agreement (as defined herein). The commitments under the Term Credit Agreement were set to expire on June 3, 2023 and were callable by us after two years at par. On February 4, 2021, we repaid all of the outstanding borrowings under and terminated the Term Credit Agreement. This termination required us to pay a make-whole fee of $55.6 million, write off debt issuance costs of $7.4 million, and pay additional termination expenses of $0.1 million. Bridge Term Credit Agreement On July 2, 2019 (the “Closing Date”), we entered into a bridge term credit agreement (the “Bridge Term Credit Agreement”) with Toronto Dominion (Texas) LLC for a $250.0 million term loan facility. Toronto Dominion (Texas) LLC and certain of its affiliates are also lenders under our Credit Agreement. Proceeds from the term loan facility were used to fund a portion of the purchase price for the Mesquite acquisition. The commitments under the Term Credit Agreement were set to expire on July 2, 2024. On June 3, 2020, we used the proceeds from the Term Credit Agreement to pay off the outstanding balance of the Bridge Term Credit Agreement. We wrote off $2.3 million of debt issuance costs which is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. Sawtooth Credit Agreement On November 27, 2019, Sawtooth, a joint venture in which we own approximately a 71.5% interest, entered into a credit agreement with Zions Bancorporation (doing business as “Amegy Bank”). The Sawtooth credit agreement has a capacity of $20.0 million. The commitments under the Sawtooth credit agreement expire on November 27, 2022. At March 31, 2021, $5.0 million had been borrowed under the Sawtooth credit agreement. The borrowings under this facility had an average interest rate of 2.36%. Commitment fees are charged at a rate of 0.50% on any unused capacity. At March 31, 2021, we were in compliance with the covenants under the Sawtooth credit agreement. Equipment Loan On October 29, 2020, we entered into an equipment loan for $45.0 million with Stonebriar Commercial Finance LLC which bears interest at a rate of 8.6% and is secured by certain of our barges and towboats. We have an aggregate principal balance of $44.1 million at March 31, 2021. The loan matures on November 1, 2027. Debt Maturity Schedule The scheduled maturities of our long-term debt are as follows at March 31, 2021: Year Ending March 31, 2026 Senior Secured Notes ABL Facility Senior Unsecured Notes Other Total (in thousands) 2022 $ — $ — $ — $ 2,184 $ 2,184 2023 — — — 7,585 7,585 2024 — — 555,251 2,816 558,067 2025 — — 380,020 3,068 383,088 2026 2,050,000 4,000 — 3,343 2,057,343 Thereafter — — 338,402 30,099 368,501 Total $ 2,050,000 $ 4,000 $ 1,273,673 $ 49,095 $ 3,376,768 Amortization of Debt Issuance Costs Amortization expense for debt issuance costs related to long-term debt was $7.8 million, $5.4 million and $4.3 million during the years ended March 31, 2021, 2020 and 2019, respectively. Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2022 $ 12,247 2023 12,247 2024 11,677 2025 10,802 2026 8,529 Thereafter 53 Total $ 55,555

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Mar. 31, 2021
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. On December 5, 2019, in response to the defendants’ post-trial motion, the Court issued an Order overturning the jury’s damages award and ordering the case to be set for a damages-only trial. Both parties filed applications with the trial court asking the trial court to certify the December 5th Order for interlocutory, immediate review by the Appellate Court. On January 7, 2020, the Supreme Court of Delaware (“Supreme Court”) entered an Order accepting an interlocutory appeal of various issues relating to both the quantum meruit and fraudulent misrepresentation verdicts. The Supreme Court heard oral arguments of the parties on November 4, 2020, took the matters presented under advisement and on January 28, 2021, issued a ruling that (a) LCT is not entitled to “benefit-of-the-bargain” damages on its fraud claim; (b) LCT is not entitled to receive fraudulent misrepresentation damages separate from its quantum meruit damages; (c) the trial court abused its discretion when it ordered a new trial on damages relating to LCT’s claim of fraudulent misrepresentation; and (d) the trial court properly ordered a new trial on LCT’s claim of quantum meruit damages. The date for a new trial, to be limited to the quantum meruit claim, has not yet been set by the trial court. Any allocation of the ultimate verdict award, if any, between the GP and the Partnership will be made by the board of directors of our general partner once all information is available to it and after the new trial, any post-trial and/or any appellate process has concluded and the verdict is final as a matter of law. As of March 31, 2021, we have accrued $2.5 million related to this matter. We are party to various other 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, 2021, we have an environmental liability, measured on an undiscounted basis, of $1.7 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 United States 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 United States 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. During the year ended March 31, 2020, we paid the final EPA settlement amount 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, 2019 $ 9,723 Liabilities incurred 1,643 Liabilities assumed in acquisitions 6,642 Liabilities settled (658) Accretion expense 1,066 Balance at March 31, 2020 18,416 Liabilities incurred 7,952 Liabilities associated with disposed assets (1) (22) Accretion expense 1,733 Balance at March 31, 2021 $ 28,079 (1) This amount relates to the sale of certain permits, land and a saltwater disposal facility (se e Note 18 ). 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. Other Commitments We have noncancelable agreements for product storage, railcar spurs and real estate. The following table summarizes future minimum payments under these agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 10,074 2023 4,568 2024 4,568 2025 74 2026 55 Thereafter 275 Total $ 19,614 As part of the Hillstone acquisition discussed in Note 4, we assumed an obligation to pay a quarterly subsidy payment in the event that specified volumetric thresholds are not exceeded at a third-party facility. This agreement expires on December 31, 2022. During the years ended March 31, 2021 and 2020, we recorded $2.6 million and $0.8 million, respectively, within operating expense in our consolidated statements of operations. At March 31, 2021, the range of potential payments we could be obligated to make pursuant to the subsidy agreement could be from $0.0 million to $5.7 million. Pipeline Capacity Agreements We have 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 prepaid expenses and other current assets and 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 following table summarizes future minimum throughput payments under these agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 35,314 2023 35,314 2024 35,410 2025 30,897 Total $ 136,935 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, 2021, we had the following commodity purchase commitments (in thousands): Crude Oil (1) Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Purchase Commitments: 2022 $ 93,285 1,515 $ 12,705 21,936 2023 — — 819 1,260 Total $ 93,285 1,515 $ 13,524 23,196 Index-Price Commodity Purchase Commitments: 2022 $ 3,038,806 54,413 $ 848,891 1,094,967 2023 1,835,567 35,588 2,848 4,774 2024 1,715,198 34,775 — — 2025 1,532,174 31,938 — — 2026 938,787 20,263 — — Total $ 9,060,532 176,977 $ 851,739 1,099,741 (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, 2021, we had the following commodity sale commitments (in thousands): Crude Oil Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Sale Commitments: 2022 $ 93,464 1,515 $ 36,731 45,827 2023 — — 2,568 3,640 Total $ 93,464 1,515 $ 39,299 49,467 Index-Price Commodity Sale Commitments: 2022 $ 3,147,543 54,634 $ 546,242 558,346 2023 1,106,564 20,988 1,686 2,088 2024 1,058,526 21,045 — — 2025 1,024,037 20,988 — — 2026 484,326 10,242 — — Total $ 6,820,996 127,897 $ 547,928 560,434 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 $37.2 million of our prepaid expenses and other current assets and $24.0 million of our accrued expenses and other payables at March 31, 2021.

Equity

Equity	12 Months Ended
	Mar. 31, 2021
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. As of March 31, 2021, we owned 8.69% of our general partner. 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 years ended March 31, 2021, 2020 and 2019, we issued 823, 4,268 and 3,039, respectively, notional units to our general partner which represented less than $0.1 million in each of the years, in order to maintain its 0.1% interest in us. Common Unit Repurchase Program On August 30, 2019, the board of directors of our general partner authorized a common unit repurchase program, under which we may repurchase up to $150.0 million of our outstanding common units through September 30, 2021 from time to time in the open market or in other privately negotiated transactions. We have not repurchased units under this program. Suspension of Common Unit and Preferred Unit Distributions The board of directors of our general partner temporarily suspended all distributions (common unit distributions beginning with the quarter ended December 31, 2020 and preferred unit distributions beginning with the quarter ended March 31, 2021) in order to deleverage our balance sheet and meet the financial performance ratios set within the Indenture of the 2026 Senior Secured Notes, as discussed further in Note 8. 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 Amount Paid to Amount Paid to (in thousands) (in thousands) 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 July 23, 2019 August 7, 2019 August 14, 2019 $ 0.3900 $ 49,217 $ 85 October 23, 2019 November 7, 2019 November 14, 2019 $ 0.3900 $ 49,936 $ 86 January 23, 2020 February 7, 2020 February 14, 2020 $ 0.3900 $ 50,056 $ 86 April 27, 2020 May 7, 2020 May 15, 2020 $ 0.2000 $ 25,754 $ 26 July 23, 2020 August 6, 2020 August 14, 2020 $ 0.2000 $ 25,754 $ 26 October 27, 2020 November 6, 2020 November 13, 2020 $ 0.1000 $ 12,877 $ 13 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, which have an exercise price of $0.01. As noted below, the remaining Class A Preferred Units were redeemed and all remaining warrants were exercised during the year ended March 31, 2020. We paid 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 were 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 two fiscal years: Date Declared Payment Date Amount Paid to Class A (in thousands) 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 We allocated the net proceeds on a relative fair value basis to the Class A Preferred Units, which includes the value of a beneficial conversion feature, and warrants. We recorded the accretion attributable to the beneficial conversion feature as a deemed distribution. Accretion for the beneficial conversion feature was $36.5 million and $67.2 million for the years ended March 31, 2020 and 2019, respectively. 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. On April 5, 2019, we redeemed 7,468,978 of the Class A Preferred Units. The applicable Class A redemption price was $13.389 per Class A Preferred Unit, calculated at 111.25% of $12.035 (the Class A Preferred Unit price), plus 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, all 1,458,371 outstanding warrants to purchase common units were exercised 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 price was $13.2385 per Class A Preferred Unit, calculated at 110% of $12.035 (the Class A Preferred Unit price), plus 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 on April 24, 2019 for the quarter ended March 31, 2019 of $4.0 million, or $0.3234 per unit, which was paid to the holders of the Class A Preferred Units on May 10, 2019. 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). On July 2, 2019, we issued 4,185,642 Class B Preferred Units to fund a portion of the purchase price for the Mesquite acquisition. 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 current distribution rate for the Class B Preferred Units is 9.00% per year of the $25.00 liquidation preference per unit (equal to $2.25 per unit per year). The following table summarizes distributions declared on our Class B Preferred Units during the last three fiscal years: Date Declared Record Date Payment Date Amount Per Unit Amount Paid to Class B (in thousands) March 19, 2018 April 2, 2018 April 16, 2018 $ 0.5625 $ 4,725 June 19, 2018 July 2, 2018 July 16, 2018 $ 0.5625 $ 4,725 September 12, 2018 October 1, 2018 October 15, 2018 $ 0.5625 $ 4,725 December 17, 2018 December 31, 2018 January 15, 2019 $ 0.5625 $ 4,725 March 15, 2019 April 1, 2019 April 15, 2019 $ 0.5625 $ 4,725 June 14, 2019 July 1, 2019 July 15, 2019 $ 0.5625 $ 4,725 September 16, 2019 October 1, 2019 October 15, 2019 $ 0.5625 $ 7,079 December 16, 2019 December 31, 2019 January 15, 2020 $ 0.5625 $ 7,079 March 16, 2020 March 31, 2020 April 15, 2020 $ 0.5625 $ 7,079 June 15, 2020 June 30, 2020 July 15, 2020 $ 0.5625 $ 7,079 September 15, 2020 September 30, 2020 October 15, 2020 $ 0.5625 $ 7,079 December 17, 2020 January 1, 2021 January 15, 2021 $ 0.5625 $ 7,079 For the quarter ended March 31, 2021, we did not declare or pay distributions to the holders of the Class B Preferred Units, thus the cumulative distribution for each Class B Preferred Unit is $0.5625. 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 $42.9 million (net of the underwriters’ discount of $1.4 million and estimated offering costs of $0.7 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. 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%. The current distribution rate for the Class C Preferred Units is 9.625% per year of the $25.00 liquidation preference per unit (equal to $2.41 per unit per year). The following table summarizes distributions declared on our Class C Preferred Units during the last two fiscal years: Amount Paid to Class C Date Declared Record Date Payment Date Amount Per Unit Preferred Unitholders (in thousands) June 14, 2019 July 1, 2019 July 15, 2019 $ 0.5949 $ 1,071 September 16, 2019 October 1, 2019 October 15, 2019 $ 0.6016 $ 1,083 December 16, 2019 December 31, 2019 January 15, 2020 $ 0.6016 $ 1,083 March 16, 2020 March 31, 2020 April 15, 2020 $ 0.6016 $ 1,083 June 15, 2020 June 30, 2020 July 15, 2020 $ 0.6016 $ 1,083 September 15, 2020 September 30, 2020 October 15, 2020 $ 0.6016 $ 1,083 December 17, 2020 January 1, 2021 January 15, 2021 $ 0.6016 $ 1,083 For the quarter ended March 31, 2021, we did not declare or pay distributions to the holders of the Class C Preferred Units, thus the cumulative distribution for each Class C Preferred Unit is $0.6016. Class D Preferred Units On July 2, 2019, we completed a private placement of an aggregate of 400,000 preferred units (“Class D Preferred Units”) and warrants exercisable to purchase an aggregate of 17,000,000 common units for an aggregate purchase price of $400.0 million. The private placement resulted in aggregate net proceeds to us of approximately $385.4 million (net of a closing fee of $14.6 million payable to affiliates of the purchasers and certain estimated expenses and expense reimbursements). We allocated the net proceeds, on a relative fair value basis, to the Class D Preferred Units ($343.7 million) and warrants ($41.7 million). Proceeds from this issuance of Class D Preferred Units were used to fund a portion of the purchase price for the Mesquite acquisition. On October 31, 2019, we completed a private placement of an aggregate of 200,000 Class D Preferred Units and warrants exercisable to purchase an aggregate of 8,500,000 common units for an aggregate purchase price of $200.0 million. The private placement resulted in aggregate net proceeds to us of approximately $194.7 million (net of a closing fee of $5.3 million payable to affiliates of the purchasers and certain estimated expenses and expense reimbursements). We allocated the net proceeds, on a relative fair value basis, to the Class D Preferred Units ($183.6 million) and warrants ($11.1 million). Proceeds from this issuance of Class D Preferred Units were used to fund a portion of the purchase price for the Hillstone acquisition (see Note 4). The holders of the Class D Preferred Units are entitled to receive a cumulative, quarterly distribution in arrears on each Class D Preferred Unit then held at an annual rate of (i) 9.00% per annum for all periods during which the Class D Preferred Units are outstanding beginning on the Closing Date and ending on the date and including the last day of the eleventh full quarter following the Closing Date, (ii) 10.00% per annum for all periods during which the Class D Preferred Units are outstanding beginning on and including the first day of the twelfth full quarter following the Closing Date and ending on the last day of the nineteenth full quarter following the Closing Date, and (iii) thereafter, 10.00% per annum or, at the purchasers’ election from time to time, a floating rate equal to the applicable three-month LIBOR, plus 7.00% per annum. The current distribution rate for the Class D Preferred Units is 9.00% per year per unit (equal to $90.00 per unit per year). The following table summarizes cash distributions declared on our Class D Preferred Units during the last two fiscal years: Amount Paid to Class D Date Declared Record Date Payment Date Amount Per Unit Preferred Unitholders (in thousands) October 23, 2019 November 7, 2019 November 14, 2019 $ 11.25 $ 4,450 January 23, 2020 February 7, 2020 February 14, 2020 $ 11.25 $ 6,075 April 27, 2020 May 7, 2020 May 15, 2020 $ 11.25 $ 6,868 July 23, 2020 August 6, 2020 August 14, 2020 $ 11.25 $ 6,946 October 27, 2020 November 6, 2020 November 13, 2020 $ 26.01 $ 15,608 January 20, 2021 February 5, 2021 February 12, 2021 $ 26.01 $ 15,608 For the quarter ended March 31, 2021, we did not declare or pay distributions to the holders of the Class D Preferred Units, thus the average cumulative distribution at March 31, 2021 for each Class D Preferred Unit is $26.01. The distributions for the quarters ended September 30, 2020 and December 31, 2020 include a 1.0% rate increase due to us exceeding the adjusted total leverage ratio, as defined within the Amended and Restated Partnership Agreement. The distributions paid in cash for the three months ended June 30, 2020 of $6.9 million represented 50% of the Class D Preferred Units distributions amount, as represented in the table above. In accordance with the terms of our Amended and Restated Partnership Agreement, the value of each Class D Preferred Unit automatically increased by the non-cash accretion which was approximately $6.9 million in the aggregate with respect to the distribution for the three months ended June 30, 2020. The distributions paid in cash for the year ended March 31, 2020 of $17.4 million represented 50% of the Class D Preferred Units distribution amount. In accordance with the terms of our Amended and Restated Partnership Agreement, the value of each Class D Preferred Unit automatically increased by the non-cash accretion, which was approximately $17.4 million in the aggregate with respect to the distributions for the year ended March 31, 2020. At any time after the Closing Date, the Partnership shall have the right to redeem all of the outstanding Class D Preferred Units at a price per Class D Preferred Unit equal to the sum of the then-unpaid accumulations with respect to such Class D Preferred Unit and the greater of either the applicable multiple on invested capital or the applicable redemption price based on an applicable internal rate of return, as more fully described in the Amended and Restated Partnership Agreement. At any time on or after the eighth anniversary of the Closing Date, each Class D Preferred Unitholder will have the right to require the Partnership to redeem on a date not prior to the 180th day after such anniversary all or a portion of the Class D Preferred Units then held by such preferred unitholder for the then-applicable redemption price, which may be paid in cash or, at the Partnership’s election, a combination of cash and a number of common units not to exceed one-half of the aggregate then-applicable redemption price, as more fully described in the Amended and Restated Partnership Agreement. Upon a Class D Change of Control (as defined in the Amended and Restated Partnership Agreement), each Class D Preferred Unitholder will have the right to require the Partnership to redeem the Class D Preferred Units then held by such Preferred Unitholder at a price per Class D Preferred Unit equal to the applicable redemption price. The Class D Preferred Units generally will not have any voting rights, except with respect to certain matters which require the vote of the Class D Preferred Units. The Class D Preferred Units generally do not have any voting rights, except that the Class D Preferred Units shall be entitled to vote as a separate class on any matter on which unitholders are entitled to vote that adversely affects the rights, powers, privileges or preferences of the Class D Preferred Units in relation to other classes of Partnership Interests (as defined in the Amended and Restated Partnership Agreement) or as required by law. The consent of a majority of the then-outstanding Class D Preferred Units, with one vote per Class D Preferred Unit, shall be required to approve any matter for which the preferred unitholders are entitled to vote as a separate class or the consent of the representative of the Class D Preferred Unitholders, as applicable. The warrants issued in the July 2, 2019 private placement are exercisable for, in the aggregate, 17,000,000 common units, of which 10,000,000 were issued with an exercise price of $17.45 per common unit (the “Premium Warrants”), and the remaining warrants to purchase 7,000,000 common units were issued with an exercise price of $14.54 per common unit (the “Par Warrants”). The warrants issued in the October 31, 2019 private placement are exercisable for, in the aggregate, 8,500,000 common units, of which, 5,000,000 were issued with an exercise price of $16.28 per common unit, and the remaining warrants to purchase 3,500,000 common units were issued with an exercise price of $13.56 per common unit. The warrants may be exercised from and after the first anniversary of the date of issuance. Unexercised warrants will expire on the tenth anniversary of the date of issuance. The warrants will not participate in cash distributions. Upon a change of control, all unvested warrants shall immediately vest and be exercisable in full. A change of control occurs when (a) the current general partner owners cease to own, directly or indirectly, at least 50% of the outstanding voting securities of the general partner, (b) the general partner withdraws or is removed by the limited partners, (c) the common units are no longer listed on a national exchange, or (d) the general partners and/or its affiliates become beneficial owner, directly or indirectly, of 80% or more of the outstanding common units or any transaction or event that occurs due to default on our credit agreement. Board Rights Agreement In connection with the issuance of the Class D Preferred Units, we entered into a board rights agreement pursuant to which affiliates of the purchasers of the Class D Preferred Units (“Purchasers”) will have the right to designate one director on the board of directors of our general partner, so long as the Purchasers and their respective affiliates, in the aggregate, own either at least (i) (A) 50% of the number of Class D Preferred Units issued on the Closing Date or (B) 50% of the aggregate liquidation preference of any class or series of Class D Parity Securities (as defined in the Amended and Restated Partnership Agreement), or (ii) warrants and/or common units that, in the aggregate, comprise 10% or more of the then-outstanding common units. Amended and Restated Partnership Agreement On February 4, 2021, NGL Energy Holdings LLC executed the First Amendment to the Seventh Amended and Restated Agreement of Limited Partnership for the purpose of amending certain consent rights in relation to the Class D Preferred Units. On October 31, 2019, NGL Energy Holdings LLC executed the Seventh Amended and Restated Agreement of Limited Partnership. The preferences, rights, powers and duties of holders of Class D Preferred Units are defined in the Amended and Restated Partnership Agreement. The Class D Preferred Units rank senior to the common units with respect to payment of distributions and distribution of assets upon liquidation, dissolution and winding up, and are in parity with the Class B Preferred Units and Class C Preferred Units. The Class D Preferred Units have no stated maturity, but we may redeem the Class D Preferred Units at any time after the Closing Date or upon the occurrence of a change in control. 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. 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 through the vesting date (the “Service Awards”). 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 Service Awards during the vesting period. The following table summarizes the Service Award activity during the years ended March 31, 2021, 2020 and 2019: 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 Units granted 2,211,431 Units vested and issued (2,938,481) Units forfeited (209,925) Unvested Service Award units at March 31, 2020 1,371,425 Units granted 7,000 Units vested and issued (892,450) Units forfeited (39,000) Unvested Service Award units at March 31, 2021 446,975 The weighted-average grant prices for March 31, 2021, 2020 and 2019 were $3.76, $12.84 and $9.74, respectively. In connection with the vesting of certain restricted units during the year ended March 31, 2021, we canceled 70,226 of the newly-vested common units in satisfaction of $0.2 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. As of March 31, 2021, we had 446,975 unvested Service Award units which will vest during the year ended March 31, 2022. 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, 2021, 2020 and 2019, we recorded compensation expense related to Service Award units of $4.7 million, $8.5 million and $12.0 million, respectively. During the year ended March 31, 2021, no units were granted as performance bonuses. Of the restricted units granted and vested during the years ended March 31, 2020 and 2019, 1,886,131 and 1,922,618 units, respectively, were granted for performance bonuses. The total amount of the bonus payment for the year ended March 31, 2020 was $24.5 million, of which we had accrued $8.7 million as of March 31, 2019. The total amount of the bonus payment for the year ended March 31, 2019 was $22.8 million, of which we had accrued $6.3 million as of March 31, 2018. As of March 31, 2021, we had estimated future expense of $1.7 million on unvested Service Award units which we expect to record during the year ended March 31, 2022. Beginning in April 2015, our general partner granted units to certain employees 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”). 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 Award 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 Award 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 year ended March 31, 2019: 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 Award units with the July 1, 2018 vesting date are considered to be forfeited. The fair value of the Performance Awards was 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. During the year ended March 31, 2019, 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)). As of March 31, 2021, there are approximately 3.3 million common units remaining available for issuance under the LTIP. Prior to the expiration of the LTIP on May 10, 2021, we granted approximately 3.3 million common units as Service Awards, which will vest in our 2022 and 2023 fiscal years. Due to the LTIP expiring, we have no common units available for grant and any current unvested Service Awards that are forfeited, canceled or expire will not be available for future grants.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	12 Months Ended
	Mar. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial InstrumentsOur 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, 2021 March 31, 2020 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 12,312 $ (17,857) $ 64,037 $ (2,235) Level 2 measurements 37,520 (24,474) 25,217 (17,635) 49,832 (42,331) 89,254 (19,870) Netting of counterparty contracts (1) (12,648) 12,648 (2,282) 2,282 Net cash collateral provided (held) 2,660 5,543 (50,104) (370) Commodity derivatives $ 39,844 $ (24,140) $ 36,868 $ (17,958) (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, 2021 2020 (in thousands) Prepaid expenses and other current assets $ 39,844 $ 36,868 Accrued expenses and other payables (21,562) (17,777) Other noncurrent liabilities (2,578) (181) Net commodity derivative asset $ 15,704 $ 18,910 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, 2021: Crude oil fixed-price (1) April 2021–December 2023 (1,850) $ (5,414) Propane fixed-price (1) April 2021–December 2023 (195) 2,188 Refined products fixed-price (1) April 2021–January 2022 (503) 1,928 Butane fixed-price (1) April 2021–March 2022 (753) (3,764) Other April 2021–June 2022 12,563 7,501 Net cash collateral provided 8,203 Net commodity derivative asset $ 15,704 At March 31, 2020: Crude oil fixed-price (1) April 2020–December 2021 (2,252) $ 41,721 Propane fixed-price (1) April 2020–December 2021 415 (738) Refined products fixed-price (1) April 2020–January 2021 (26) 27,401 Other April 2020–March 2022 1,000 69,384 Net cash collateral held (50,474) Net commodity derivative asset $ 18,910 (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. The following table summarizes the net (losses) gains 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, 2021 $ (83,578) 2020 $ 85,941 2019 $ 10,817 Amounts in the table above do not include net (losses) gains 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 19). 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, 2021, 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 ABL Facility is variable-rate debt with interest rates that are generally indexed to the Wall Street Journal prime rate or LIBOR interest rate (or successor rate). At March 31, 2021, we had $4.0 million of outstanding borrowings under the ABL Facility at a weighted average interest rate of 5.25%. The Sawtooth credit agreement is variable-rate debt with interest rates that are generally indexed to the rate the lender announces from time to time as its prime rate or base commercial lending rate or LIBOR interest rate (or successor rate). At March 31, 2021, we had $5.0 million of outstanding borrowings under the Sawtooth credit agreement at an average interest rate of 2.36%. Fair Value of Fixed-Rate Notes The following table provides fair values estimates of our fixed-rate notes at March 31, 2021 (in thousands): Senior Secured Notes: 2026 Senior Secured Notes $ 2,114,917 Senior Unsecured Notes: 2023 Notes $ 535,817 2025 Notes $ 322,384 2026 Notes $ 287,924 For the 2026 Senior Secured Notes and Senior Unsecured Notes, the fair value estimates were developed based on publicly traded quotes and would be classified as Level 2 in the fair value hierarchy.

Segments

Segments	12 Months Ended
	Mar. 31, 2021
Segment Reporting [Abstract]
Segments	SegmentsThe following table summarizes revenues related to our segments for the periods indicated. During the three months ended March 31, 2021, we changed the name of our Liquids and Refined Products segment to Liquids Logistics. 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, 2021 2020 2019 (in thousands) Revenues: Water Solutions: Topic 606 revenues Disposal service fees $ 317,640 $ 330,877 $ 217,545 Sale of recovered crude oil 28,599 59,445 72,678 Sale of brackish non-potable water 10,554 11,676 2,404 Other service revenues 14,193 20,061 9,017 Non-Topic 606 revenues — — 42 Total Water Solutions revenues 370,986 422,059 301,686 Crude Oil Logistics: Topic 606 revenues Crude oil sales 1,574,699 2,383,812 3,011,355 Crude oil transportation and other 142,233 170,138 148,738 Non-Topic 606 revenues 11,355 13,991 12,598 Elimination of intersegment sales (6,651) (18,174) (36,056) Total Crude Oil Logistics revenues 1,721,636 2,549,767 3,136,635 Liquids Logistics: Topic 606 revenues Refined products sales 1,123,963 2,399,642 2,535,243 Propane sales 1,023,479 842,400 1,169,117 Butane sales 516,358 562,053 628,063 Other product sales 373,707 484,373 592,889 Service revenues 22,270 37,938 26,655 Non-Topic 606 revenues 79,442 289,713 320,798 Elimination of intersegment sales (6,073) (4,983) (23,291) Total Liquids Logistics revenues 3,133,146 4,611,136 5,249,474 Corporate and Other: Non-Topic 606 revenues 1,255 1,038 1,362 Total Corporate and Other revenues 1,255 1,038 1,362 Total revenues $ 5,227,023 $ 7,584,000 $ 8,689,157 The following table summarizes depreciation and amortization expense (including amortization expense recorded within interest expense, cost of sales and operating expenses in Note 7 and Note 8) and operating income (loss) by segment for the periods indicated. Year Ended March 31, 2021 2020 2019 (in thousands) Depreciation and Amortization: Water Solutions $ 222,354 $ 163,874 $ 108,162 Crude Oil Logistics 60,874 70,759 74,245 Liquids Logistics 29,503 28,279 27,034 Corporate and Other 18,469 13,936 12,233 Total depreciation and amortization $ 331,200 $ 276,848 $ 221,674 Operating Income (Loss): Water Solutions $ (92,720) $ (173,064) $ 210,525 Crude Oil Logistics (304,330) 117,768 (7,379) Liquids Logistics 70,441 142,411 9,288 Corporate and Other (64,144) (90,447) (85,706) Total operating (loss) income $ (390,753) $ (3,332) $ 126,728 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, 2021 2020 2019 (in thousands) Water Solutions $ 66,649 $ 2,076,866 $ 567,637 Crude Oil Logistics 9,933 28,828 28,039 Liquids Logistics 31,172 19,753 72,717 Corporate and Other 11,953 7,968 1,819 Total $ 119,707 $ 2,133,415 $ 670,212 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 (see Note 19). The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, operating lease right-of-use assets and goodwill) and total assets by segment at the dates indicated: March 31, 2021 2020 (in thousands) Long-lived assets, net: Water Solutions $ 3,104,450 $ 3,382,727 Crude Oil Logistics 1,090,578 1,567,503 Liquids Logistics (1) 626,221 654,530 Corporate and Other 44,802 33,570 Total $ 4,866,051 $ 5,638,330 (1) Includes $20.9 million and $25.9 million of non-US long-lived assets at March 31, 2021 and 2020, respectively. March 31, 2021 2020 (in thousands) Total assets: Water Solutions $ 3,204,850 $ 3,539,328 Crude Oil Logistics 1,665,005 1,886,211 Liquids Logistics (1) 1,003,370 972,684 Corporate and Other 74,116 100,513 Total $ 5,947,341 $ 6,498,736 (1) Includes $37.9 million and $37.8 million of non-US total assets at March 31, 2021 and 2020, respectively.

Transactions with Affiliates

Transactions with Affiliates	12 Months Ended
	Mar. 31, 2021
Related Party Transactions [Abstract]
Transactions with Affiliates	Transactions with Affiliates A member of the board of directors of our general partner was 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 produced water and solids received from WPX. On January 7, 2021, Devon Energy Corporation (“Devon”) acquired WPX and the member of the board of directors of our general partner has since retired from WPX/Devon. Due to his retirement, we will no longer be classifying transactions with WPX or Devon as related party transactions after December 31, 2020. 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. In December 2019, Energy Transfer LP (“ET”) acquired SemGroup. During the three months ended December 31, 2019, we reevaluated our related parties and determined that SemGroup/ET no longer meet the criteria to be disclosed as a related party. For the tables below, information for the year ended March 31, 2019 and six months ended September 30, 2019 have been retained but we have not disclosed any information related to transactions subsequent to September 30, 2019. The following table summarizes our related party transactions for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands) Sales to WPX $ 39,129 $ 48,222 $ 28,026 Purchases from WPX (1) $ 216,487 $ 313,578 $ 329,525 Sales to SemGroup $ 458 $ 1,114 Purchases from SemGroup $ — $ 4,395 Sales to entities affiliated with management $ 18,402 $ 8,367 $ 21,385 Purchases from entities affiliated with management $ 1,239 $ 3,799 $ 4,382 Sales to equity method investees $ — $ 203 $ — Purchases from equity method investees $ 3,249 $ 2,120 $ — (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, 2021 2020 (in thousands) NGL Energy Holdings LLC $ 8,245 $ 7,781 WPX — 3,563 Entities affiliated with management 728 151 Equity method investees 462 1,439 Total $ 9,435 $ 12,934 Accounts payable to affiliates consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) WPX $ — $ 17,039 Entities affiliated with management 12 149 Equity method investees 107 529 Total $ 119 $ 17,717 Other Related Party Transactions 2026 Senior Secured Notes and ABL Facility To complete the issuance of the 2026 Senior Secured Notes and the ABL Facility (see Note 8), we were required to receive the consent of the holders of our Class D Preferred Units, who are represented on the board of directors of our general partner. For their consent, we paid to the holders of the Class D Preferred Units $40.0 million. Acquisition of Interest in KAIR2014 LLC During the three months ended June 30, 2019, we purchased a 50% interest in an aircraft company, KAIR2014 LLC, for $0.9 million in cash and accounted for our interest using the equity method of accounting (see Note 2). The remaining interest in KAIR2014 LLC is owned by our Chief Executive Officer, H. Michael Krimbill. Acquisition of Interest in NGL Energy Holdings LLC During the year ended March 31, 2020, we purchased, in three transactions, a 2.97% interest in our general partner, NGL Energy Holdings LLC, for $3.8 million in cash and accounted for this as a deduction within limited partners’ equity in our consolidated balance sheet. We also purchased a 5.73% interest in our general partner, NGL Energy Holdings LLC, for $11.5 million in cash and accounted for this as a deduction within limited partners’ equity in our consolidated balance sheet. This interest was purchased from a fund controlled by The Energy & Minerals Group, which is represented on the board of directors of our general partner. Victory Propane, LLC On August 14, 2018, we sold our 50% interest in Victory Propane, LLC (“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 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. 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 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 on disposal or impairment of assets, net. Repurchase of Warrants On April 26, 2018, 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 10).

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
	Mar. 31, 2021
Defined Contribution Plan [Abstract]
Employee Benefit Plan	Employee Benefit PlanWe 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 vest over two years. Effective January 1, 2020, for every dollar that employees contribute up to 4% of their eligible compensation (as defined in the plan), we contribute one dollar, plus 50 cents for every dollar employees contribute between 4% and 6% of their eligible compensation (as defined in the plan). Expenses under the plan for the years ended March 31, 2021, 2020 and 2019 were $3.4 million, $2.3 million and $1.9 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 19).

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Mar. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	Revenue from Contracts with CustomersEffective 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. Our costs to obtain or fulfill our revenue contracts were not material as of March 31, 2021. 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 842, respectively. See Note 12 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Liquids Logistics segment includes $11.0 million of net gains related to changes in the mark-to-market value of these arrangements recorded during the year ended March 31, 2021. 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. 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 produced water and solids for disposal at our facilities. In cases where we have agreed within a contract or are required by law to remove crude oil from the produced water, 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 produced water 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 the estimate 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 throughout each reset period. 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 produced water or solids we accept from the customer. For contracts that involve the sale of recovered crude oil and brackish non-potable water, we will recognize revenue at a point in time, based on when control of the product is transferred to the customer. 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. Liquids Logistics Performance Obligations Within the Liquids Logistics 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. All revenue from services is recognized over time utilizing the output method based on volumes stored or moved. 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, 2021 (in thousands): Year Ending March 31, 2022 $ 111,966 2023 101,702 2024 78,241 2025 56,288 2026 17,732 Thereafter 5,667 Total $ 371,596 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 Logistics 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 the estimate 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. Contract Assets and Liabilities The following tables summarize the balances of our contract assets and liabilities at the dates indicated: March 31, 2021 March 31, 2020 (in thousands) Accounts receivable from contracts with customers $ 436,682 $ 372,930 Contract liabilities balance at March 31, 2020 $ 19,536 Payment received and deferred 36,861 Payment recognized in revenue (45,234) Contract liabilities balance at March 31, 2021 $ 11,163

Leases

Leases	12 Months Ended
	Mar. 31, 2021
Leases [Abstract]
Leases	Leases We adopted ASC 842 effective April 1, 2019 using the modified retrospective method, with no adjustment to comparative period information, which remains reported under ASC 840, and no cumulative effect adjustment to equity. Upon adoption, we recorded operating lease right-of-use assets of $551.2 million and operating lease obligations of $549.0 million, including amounts classified as assets and liabilities held for sale as of April 1, 2019. The adoption of this standard did not impact our unaudited condensed consolidated statement of operations or unaudited condensed consolidated statement of cash flows for the three months ended June 30, 2019. We also elected the following transitional practical expedients, which allowed us to (i) not evaluate land easements prior to April 1, 2019; (ii) use hindsight in determining the lease term; (iii) not reassess whether current or expired contracts contain leases; (iv) not reassess the lease classification for any expired or existing leases; and (v) not reassess initial costs. Lessee Accounting Our leasing activity primarily consists of product storage, office space, real estate, railcars, and equipment. We determine if an agreement contains a lease at the inception of the arrangement. If an arrangement is determined to contain a lease, we classify the lease as an operating lease or a finance lease depending on the terms of the arrangement. All of our leases are classified as operating leases. Operating lease right-of-use assets represent our right to use an underlying asset for the lease term when we control the use of the asset by obtaining substantially all of the economic benefits of the asset and direct the use of the asset. Operating lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and operating lease liabilities with an initial term of greater than one year are recognized at the commencement date based on the present value of lease payments over the lease term. As our leases do not provide an implicit interest rate, we use our incremental borrowing rate based on the information available at the commencement date in determining the present value of lease payments. Our incremental borrowing rate represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We do not have any leases that provide for guarantees of residual value. Our lease agreements may include options to extend or terminate the lease which are included in the measurement of our operating lease liability when it is reasonably certain that we will exercise the option. Lease renewal terms vary from one year to 30 years. Operating lease expense is recognized on a straight-line basis over the lease term. We have variable lease payments, including adjustments to lease payments based on an index or rate, such as a consumer price index, fair value adjustments to lease payments, and common area maintenance, real estate taxes, and insurance payments in certain real estate leases. We also have certain land leas es within our Water Solutions segment that require us to pay a royalty, which could be based on a flat rate per barrel disposed or a percentage of revenue generated. Variable lease payments are excluded from operating lease right-of-use assets and operating lease liabilities and are expensed as incurred. Operating lease right-of-use assets also include any lease prepayments and exclude lease incentives. For leases acquired as a result of an acquisition, the right-of-use asset also includes adjustments for any favorable or unfavorable market terms present in the lease. Short-term leases with an initial term of 12 months or less that do not include a purchase option, with the exception of railcar leases, are not recorded on the consolidated balance sheet. Operating lease expense for short-term leases is recognized on a straight-line basis over the lease term and amounts related to short-term leases are disclosed within our consolidated financial statements. We have lease agreements with lease and non-lease components, which are generally accounted for separately. For certain leases of buildings and land, we account for the lease and non-lease components as a single lease component based on the election of the practical expedient to not separate lease components from non-lease components. At March 31, 2021, we had operating lease right-of-use assets of $152.1 million and current and noncurrent operating lease obligations of $47.1 million and $103.6 million, respectively, on our consolidated balance sheet. At March 31, 2020, we had operating lease right-of-use assets of $180.7 million and current and noncurrent operating lease obligations of $56.8 million and $121.0 million, respectively, on our consolidated balance sheet. At March 31, 2021, the weighted-average remaining lease term and weighted-average discount rate for our operating leases was 6.88 years and 7.06%, respectively. At March 31, 2020, the weighted-average remaining lease term and weighted-average discount rate for our operating leases was 6.74 years and 6.06%, respectively. The following table summarizes the components of our lease expense for the periods indicated: Year Ended March 31, 2021 2020 (in thousands) Operating lease expense $ 69,031 $ 72,340 Variable lease expense 18,871 19,158 Short-term lease expense 1,217 799 Total lease expense $ 89,119 $ 92,297 Amounts in the table above do not include lease expense related to TPSL and Gas Blending, as these amounts have been classified within discontinued operations within our consolidated statement of operations for all periods presented (see Note 19). Rental expense relating to operating leases was $91.6 million for the year ended March 31, 2019, which does not include rental expense related to Mid-Con, Gas Blending, TPSL and our former Retail Propane segment, as these amounts have been classified within discontinued operations in our consolidated statements of operations for all periods presented (see Note 19). The following table summarizes maturities of our operating lease obligations at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 53,842 2023 41,395 2024 26,589 2025 15,349 2026 7,406 Thereafter 50,804 Total lease payments 195,385 Less imputed interest (44,678) Total operating lease obligations $ 150,707 The following table summarizes supplemental cash flow and non-cash information related to our operating leases for the periods indicated: Year Ended March 31, 2021 2020 (1) (in thousands) Cash paid for amounts included in the measurement of operating lease obligations $ 68,141 $ 101,678 Operating lease right-of-use assets obtained in exchange for operating lease obligations $ 33,579 $ 598,734 (1) Amounts include the leases and activity for TPSL and Gas Blending which were sold during the year ended March 31, 2020 (see Note 19). Lessor Accounting and Subleases Our lessor arrangements include storage and railcar contracts, of which certain agreements contain renewal options for periods of between one year and five years. We determine if an agreement contains a lease at the inception of the arrangement. If an arrangement is determined to contain a lease, we classify the lease as operating, sales-type or direct financing. Lessor accounting under ASC 842 is substantially unchanged and all of our leases will continue to be classified as operating leases. We also, from time to time, sublease certain of our storage capacity and railcars to third parties. Fixed rental revenue is recognized on a straight-line basis over the lease term. During the years ended March 31, 2021 and 2020, fixed rental revenue was $15.9 million and $20.4 million, which includes $2.5 million and $4.6 million of sublease revenue, respectively. The following table summarizes future minimum lease payments receivable under various noncancelable operating lease agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 11,944 2023 8,959 2024 4,817 2025 690 2026 416 Thereafter 800 Total $ 27,626

Allowance for Current Expected

Allowance for Current Expected Credit Loss	12 Months Ended
	Mar. 31, 2021
Credit Loss [Abstract]
Allowance for Current Expected Credit Loss	Allowance for Current Expected Credit Loss (CECL)ASU 2016-13 requires that an allowance for expected credit losses be recognized for certain financial assets that reflects the current expected credit loss over the financial asset’s contractual life. The valuation allowance considers the risk of loss, even if remote, and considers past events, current conditions and reasonable and supportable forecasts. We are exposed to credit losses primarily through sale of products and services and notes receivable from third-parties. A counterparty’s ability to pay is assessed through a credit process that considers the payment terms, the counterparty’s established credit rating or our assessment of the counterparty’s credit worthiness and other risks. We can require prepayment or collateral to mitigate credit risks. We group our financial assets into pools of counterparties with similar risk characteristics for the purpose of determining the allowance for expected credit losses. Each reporting period, we assess whether a significant change in the risk of expected credit loss has occurred. Among the quantitative and qualitative factors considered in calculating our allowance for expected credit losses are historical financial data, including write-offs and allowances, current conditions, industry risk and current credit ratings. Financial assets will be written off in whole, or in part, when practical recovery efforts have been exhausted and no reasonable expectation of recovery exists. Subsequent recoveries of amounts previously written off are recorded as an increase to the allowance. We manage receivable pools using past due balances as a key credit quality indicator. The following table summarizes changes in our expected credit loss allowance for accounts receivable - trade for the periods indicated: Year Ended March 31, 2021 2020 (1) 2019 (1) (in thousands) Balance at beginning of year $ 4,540 $ 4,016 $ 3,851 Cumulative effect adjustment 433 — — Current period provision for expected credit losses 319 1,202 381 Write-offs charged against the allowance (3,100) (678) (216) Balance at end of year $ 2,192 $ 4,540 $ 4,016 (1) We adopted ASU No. 2016-13 as of April 1, 2020. The allowance reported for the years ended March 31, 2020 and 2019 has not been changed from its previous presentation. The following table summarizes changes in our expected credit loss allowance for notes receivable and other for the period indicated: Year Ended March 31, 2021 (1) (in thousands) Balance at beginning of year $ — Cumulative effect adjustment 680 Write-offs charged against the allowance (222) Balance at end of year $ 458 (1) We adopted ASU No. 2016-13 as of April 1, 2020. An allowance had not been established for notes receivable and other prior to the adoption of ASU No. 2016-13. In addition to the provision for expected credit losses above, we also wrote off $5.7 million during the year ended March 31, 2021 as discussed in Note 18.

Other Matters

Other Matters	12 Months Ended
	Mar. 31, 2021
Other Matters
Other Matters	Other Matters Third-party Loan Receivable As discussed previously in Note 2, we had an outstanding loan receivable of $26.7 million, including accrued interest, associated with our interest in the Facility that is utilized by a third party. Our loan receivable was secured by title to and a lien interest on the Facility. The third party filed a petition for bankruptcy under Chapter 11 of the bankruptcy code in July 2019, at which time we filed our Proof of Claim within the bankruptcy case. The Chapter 11 plan, as supplemented, was approved by the bankruptcy court in February 2020, pursuant to which we were expected to be paid a $26.7 million secured claim as an unimpaired creditor. After the approval of the supplemental plan, the third party attempted to negotiate with us to accept an amount less than the full amount of our claim or to take back the Facility in kind. In May 2020, we filed a motion with the bankruptcy court to compel the third party to pay us the full amount of the claim in accordance with the approved plan. The bankruptcy court ruled in May 2020 that the third party would need to either pay us the full amount of the claim or deliver the Facility to us at a destination of our reasonable choosing. On June 26, 2020, we settled our claim with the third party and agreed to receive $16.3 million, for which we released any and all claims and/or liens with respect to the Facility and transferred title of the Facility to the third party. For the remaining $10.4 million of the loan receivable, we have filed an unsecured claim within the bankruptcy. As of June 30, 2020, we wrote-off approximately $9.4 million, the portion of the unsecured claimed we have deemed uncollectible, and this amount was recorded as a loss within loss (gain) on disposal or impairment of assets, net in our unaudited condensed consolidated statement of operations. As of March 31, 2021, the remaining balance of $0.6 million, net of an allowance for an expected credit loss, is recorded within prepaid expenses and other current assets in our consolidated balance sheet. Third-party Bankruptcy During the three months ended June 30, 2020, Extraction, who is a significant shipper on our crude oil pipeline, filed a petition for bankruptcy under Chapter 11 of the bankruptcy code. Extraction has transportation contracts pursuant to which it has committed to ship crude oil on our pipeline through October 2026. As part of the bankruptcy filing, Extraction requested that the court authorize it to reject these transportation contracts, effective June 14, 2020. We disputed its ability to reject the transportation contracts, filed objections and took various other legal steps within the bankruptcy proceedings to protect the value to us of the contracts at issue. On November 2, 2020, the bankruptcy court issued a bench ruling granting Extraction’s motion to reject the transportation contracts effective as of June 14, 2020. We disputed the rejection motion and appealed the bankruptcy court’s approval of the rejection of the transportation contracts. On December 21, 2020, we announced a global settlement agreement with Extraction, as it relates to Extraction’s emergence from bankruptcy, which occurred on January 21, 2021. Among other consideration, the global settlement agreement provides for the following: (i) a new long-term supply agreement, which includes a significant acreage dedication in the DJ Basin, and retains Extraction’s crude oil volumes for shipping on our Grand Mesa Pipeline; (ii) a new rate structure under the supply agreement which is based on calendar month average New York Mercantile Exchange (“NYMEX”) prices with an agreed upon differential plus an increase in the rate when those NYMEX prices exceed $50.00 per barrel; and (iii) the receipt of $35.0 million from Extraction as a liquidated payment for our unsecured claims, which was received on January 21, 2021. Due to entering into a new supply agreement and withdrawing our appeal of the rejection of our transportation contract, we determined that the customer commitment intangible asset related to one of the transportation contracts was impaired as of December 31, 2020. We recorded an impairment charge of $145.8 million , which was calculated as the difference between the carrying value of the intangible asset of $180.8 million and the $35.0 million received from Extraction. We recorded the impairment charge within loss on disposal or impairment of assets, net in our consolidated statement of operations for the year ended March 31, 2021 . We also determined, as a result of these transactions, that it was more likely than not, that the fair value of our Crude Oil Logistics reporting unit was less than its carrying value and assessed goodwill for impairment, which resulted in an impairment charge of $237.8 million . See Note 6 for a further discussion of the impairment of goodwill. Extraction continued to utilize, during the bankruptcy period, the services under the transportation contracts by nominating and delivering barrels to be shipped on our pipeline. During the three months ended September 30, 2020, Extraction paid us for the barrels that have actually been shipped, but did not pay for the difference between the minimum volume commitment specified under the contracts and the actual volumes shipped (“deficiency volumes”). The amount owed by Extraction related to the deficiency volumes is $5.7 million. Following our global settlement, we deemed this amount uncollectible and wrote off the entire amount to bad debt expense within our consolidated statement of operations during the year ended March 31, 2021. Extraction also has a water disposal contract with our Water Solutions segment whereby we dispose of its produced water for a fee. On August 10, 2020, they filed a motion with the bankruptcy court to also reject our water disposal contract but subsequently filed a motion to remove that contract from the list of contracts it was asking the court for permission to reject. Since the filing of the bankruptcy petition, Extraction continued, and has continued after emerging from bankruptcy, to utilize the services under the water disposal contract. We received payment for all prepetition services and they are current on all of its post-filing date receivables. Sale of Certain Assets During the three months ended December 31, 2020, we sold certain permits, land and a saltwater disposal facility to WaterBridge Resources LLC for total proceeds of $43.2 million, of which $0.3 million remains held back until satisfaction of certain conditions. We recorded a gain of $14.0 million within loss on disposal or impairment of assets, net in our consolidated statement of operations for the year ended March 31, 2021 . 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 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. As part of this transaction, WaterBridge Resources LLC also has the option to acquire additional land and permits once the permitting process has been completed. During the year ended March 31, 2020, WaterBridge Resources LLC acquired two additional permits and we received proceeds of $15.0 million and recorded a gain of $14.5 million. This gain is reported within loss 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 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 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. Sale of E Energy Adams, LLC On May 3, 2018, we sold our approximately 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 on disposal or impairment of assets, net in our consolidated statement of operations. Sawtooth Joint Venture As previously reported, on March 30, 2018, we formed 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. At that time, Magnum acquired an approximately 28.5% interest in Sawtooth from us . Magnum had an option to acquire our remaining 71.5% interest in Sawtooth for an additional $182.4 million by March 31, 2021, which was not exercised.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Mar. 31, 2021
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations As previously disclosed, 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 and on August 14, 2018, we sold our interest in Victory Propane (see Note 13). On September 30, 2019, we completed the sale of TPSL to Trajectory Acquisition Company, LLC for total consideration of $233.8 million , including equity consideration, inventory and net working capital. On January 3, 2020, we completed the sale of our refined products business in the mid-continent region of the United States (“Mid-Con”) to a third-party. On March 30, 2020, we completed the sale of our gas blending business in the southeastern and eastern regions of the United States (“Gas Blending”) to another third-party. As the sale of each of these businesses represented strategic shifts, the results of operations and cash flows related to these businesses are classified as discontinued operations for all periods presented. The following table summarizes the results of operations from discontinued operations for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands) Revenues $ 16,198 $ 12,186,862 $ 15,398,608 Cost of sales 16,556 12,193,307 15,338,614 Operating expenses 290 6,997 37,348 General and administrative expense — 56 2,716 Depreciation and amortization — 749 9,593 Loss (gain) on disposal or impairment of assets, net (1) 1,174 203,990 (407,608) Operating (loss) income from discontinued operations (1,822) (218,237) 417,945 Equity in earnings of unconsolidated entities — — 1,183 Interest expense — (111) (126) Other income, net — 133 837 (Loss) income from discontinued operations before taxes (2) (1,822) (218,215) 419,839 Income tax benefit (expense) 53 (20) (989) (Loss) income from discontinued operations, net of tax $ (1,769) $ (218,235) $ 418,850 (1) Amount for the year ended March 31, 2021 includes a loss of $1.0 million on the sale of Gas Blending and $0.2 million on the sale of TPSL. Amount for the year ended March 31, 2020 includes a loss of $182.1 million on the sale of TPSL, a loss of $6.3 million on the sale of Mid-Con, a loss of $14.5 million on the sale of Gas Blending and a loss of $1.0 million on the sale of virtually all of our remaining Retail Propane segment to Superior on July 10, 2018. 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 LPG on March 30, 2018 related to a working capital adjustment. (2) Amount for the year ended March 31, 2019 includes a loss attributable to redeemable noncontrolling interests of $0.4 million. Continuing Involvement As of March 31, 2021, we have commitments to sell up to 3.2 million gallons of propane, valued at $3.8 million (based on the contract price) to Superior and DCC, the purchasers of our former Retail Propane segment, through December 2021. During the year ended March 31, 2021, we received a combined $52.3 million from Superior and DCC for propane sold to them during the period.

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Mar. 31, 2021
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
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 2017 to 2020 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. We have a deferred tax liability of $45.8 million and $56.4 million at March 31, 2021 and 2020, respectively, as a result of acquiring corporations in connection with certain of our acquisitions (see Note 4), which is included within other noncurrent liabilities in our consolidated balance sheets. 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 during the year ended March 31, 2021 was $4.7 million with an effective tax rate of 39.7%. The deferred tax benefit recorded during the year ended March 31, 2020 was $2.9 million with an effective tax rate of 27.8%. 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, 2021 or 2020.
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. See Note 17 for a further discussion of our allowance for expected credit losses. 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.
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 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 Facility (as defined herein), ABL Facility (as defined herein) and the Sawtooth Caverns, LLC (“Sawtooth”) credit agreement. 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, 2021 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.
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.
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 and 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. Also, as discussed in Note 4, we made certain adjustments during the year ended March 31, 2021 to our estimates of the acquisition date fair values of the assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2020.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In November 2020, the Securities and Exchange Commission (“SEC”) issued a Final Rule, “Management’s Discussion and Analysis, Selected Financial Data, and Supplementary Financial Information”, to modernize, simplify and enhance certain financial disclosure requirements in Regulation S-K. The Final Rule eliminates Regulation S-K, Item 301. Selected Financial Data, streamlines the requirements in Item 302. Supplementary Financial Information, and updates certain requirements in Item 303. Management’s Discussion and Analysis of Financial Condition and Results of Operations. The guidance is effective for fiscal periods ending on or after August 9, 2021, although early adoption is permitted if an entity complies with an amended Item in its entirety. Effective March 31, 2021, we adopted a portion of this guidance by electing to comply with guidance related to Item 301, which eliminated the Selected Financial Data, and Item 302, which allowed us to eliminate the Quarterly Financial Data from this filing. In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity.” This ASU (i) simplifies an issuer’s accounting for convertible instruments by eliminating two of the three models in ASC 470-20 that require separate accounting for embedded conversion features, (ii) amends diluted earnings per share calculations for convertible instruments by requiring the use of the if-converted method and (iii) simplifies the settlement assessment entities are required to perform on contracts that can potentially settle in an entity’s own equity by removing certain requirements. This guidance is effective for interim and annual periods beginning after December 15, 2021, with early adoption permitted. We are currently evaluating the effect that this guidance will have on our financial position, results of operations and cash flows. In March 2020, the SEC issued “Financial Disclosures About Guarantors and Issuers of Guaranteed Securities and Affiliates Whose Securities Collateralize a Registrant’s Securities”, which amends the disclosure requirements for guarantors and issuers of guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X. The amendment simplifies the disclosure requirements and permits the amended disclosures to be provided outside the footnotes in audited annual or unaudited interim consolidated financial statements in all filings. The guidance is effective for the Partnership for fiscal periods ending after January 4, 2021, although early adoption is permitted. We adopted this guidance effective April 1, 2020 and elected to include the required summarized financial information in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations –Liquidity, Sources of Capital and Capital Resource Activities– Guarantor Summarized Financial Information .” In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” The ASU provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. This guidance is effective prospectively upon issuance through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of this ASU. We are currently evaluating the effect that this guidance will have on our financial position, results of operations and cash flows. In June 2016, the FASB issued 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 trade 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. We adopted ASU No. 2016-13 on April 1, 2020, using the modified retrospective approach with a cumulative effect adjustment of $1.1 million to opening equity at the beginning of the period of adoption. See Note 17 for a further discussion of the impact of the adoption of this ASU on our consolidated financial statements.

Commitment and Contingencies (P

Commitment and Contingencies (Policies)	12 Months Ended
	Mar. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Asset Retirement Obligation	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.

Equity (Policies)

Equity (Policies)	12 Months Ended
	Mar. 31, 2021
Equity [Abstract]
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, 2021
Revenue from Contract with Customer [Abstract]
Revenue Recognition	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. Our costs to obtain or fulfill our revenue contracts were not material as of March 31, 2021. 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 842, respectively. See Note 12 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Liquids Logistics segment includes $11.0 million of net gains related to changes in the mark-to-market value of these arrangements recorded during the year ended March 31, 2021. 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. 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 produced water and solids for disposal at our facilities. In cases where we have agreed within a contract or are required by law to remove crude oil from the produced water, 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 produced water 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 the estimate 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 throughout each reset period. 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 produced water or solids we accept from the customer. For contracts that involve the sale of recovered crude oil and brackish non-potable water, we will recognize revenue at a point in time, based on when control of the product is transferred to the customer. 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. Liquids Logistics Performance Obligations Within the Liquids Logistics 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. All revenue from services is recognized over time utilizing the output method based on volumes stored or moved. Remaining Performance Obligations

Leases (Policies)

Leases (Policies)	12 Months Ended
	Mar. 31, 2021
Leases [Abstract]
Lessee accounting policy	Our leasing activity primarily consists of product storage, office space, real estate, railcars, and equipment. We determine if an agreement contains a lease at the inception of the arrangement. If an arrangement is determined to contain a lease, we classify the lease as an operating lease or a finance lease depending on the terms of the arrangement. All of our leases are classified as operating leases. Operating lease right-of-use assets represent our right to use an underlying asset for the lease term when we control the use of the asset by obtaining substantially all of the economic benefits of the asset and direct the use of the asset. Operating lease liabilities represent our obligation to make lease payments arising from the lease. Operating lease right-of-use assets and operating lease liabilities with an initial term of greater than one year are recognized at the commencement date based on the present value of lease payments over the lease term. As our leases do not provide an implicit interest rate, we use our incremental borrowing rate based on the information available at the commencement date in determining the present value of lease payments. Our incremental borrowing rate represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We do not have any leases that provide for guarantees of residual value. Our lease agreements may include options to extend or terminate the lease which are included in the measurement of our operating lease liability when it is reasonably certain that we will exercise the option. Lease renewal terms vary from one year to 30 years. Operating lease expense is recognized on a straight-line basis over the lease term. We have variable lease payments, including adjustments to lease payments based on an index or rate, such as a consumer price index, fair value adjustments to lease payments, and common area maintenance, real estate taxes, and insurance payments in certain real estate leases. We also have certain land leas es within our Water Solutions segment that require us to pay a royalty, which could be based on a flat rate per barrel disposed or a percentage of revenue generated. Variable lease payments are excluded from operating lease right-of-use assets and operating lease liabilities and are expensed as incurred. Operating lease right-of-use assets also include any lease prepayments and exclude lease incentives. For leases acquired as a result of an acquisition, the right-of-use asset also includes adjustments for any favorable or unfavorable market terms present in the lease. Short-term leases with an initial term of 12 months or less that do not include a purchase option, with the exception of railcar leases, are not recorded on the consolidated balance sheet. Operating lease expense for short-term leases is recognized on a straight-line basis over the lease term and amounts related to short-term leases are disclosed within our consolidated financial statements. We have lease agreements with lease and non-lease components, which are generally accounted for separately. For certain leases of buildings and land, we account for the lease and non-lease components as a single lease component based on the election of the practical expedient to not separate lease components from non-lease components.
Lessor accounting policy	Our lessor arrangements include storage and railcar contracts, of which certain agreements contain renewal options for periods of between one year and five years. We determine if an agreement contains a lease at the inception of the arrangement. If an arrangement is determined to contain a lease, we classify the lease as operating, sales-type or direct financing. Lessor accounting under ASC 842 is substantially unchanged and all of our leases will continue to be classified as operating leases. We also, from time to time, sublease certain of our storage capacity and railcars to third parties. Fixed rental revenue is recognized on a straight-line basis over the lease term.

Allowance for Current Expecte_2

Allowance for Current Expected Credit Loss (Policies)	12 Months Ended
	Mar. 31, 2021
Credit Loss [Abstract]
Allowance for expected credit loss	ASU 2016-13 requires that an allowance for expected credit losses be recognized for certain financial assets that reflects the current expected credit loss over the financial asset’s contractual life. The valuation allowance considers the risk of loss, even if remote, and considers past events, current conditions and reasonable and supportable forecasts.

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Mar. 31, 2021
Accounting Policies [Abstract]
Schedule of inventories	Inventories consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) Crude oil $ 64,916 $ 18,201 Propane 45,521 25,163 Butane 19,189 9,619 Biodiesel 16,169 8,195 Ethanol 3,056 1,834 Diesel 2,252 2,414 Other 7,364 4,208 Total $ 158,467 $ 69,634
Schedule of investments in unconsolidated entities	Our investments in unconsolidated entities consist of the following at the dates indicated: Ownership March 31, Entity Segment Interest (1) Date Acquired 2021 2020 (in thousands) Water services and land company Water Solutions 50% November 2019 $ 15,832 $ 16,607 Water services and land company Water Solutions 50% November 2019 2,284 2,092 Water services and land company Water Solutions 10% November 2019 3,254 3,384 Aircraft company (2) Corporate and Other 50% June 2019 748 447 Water services company Water Solutions 50% August 2018 424 449 Natural gas liquids terminal company Liquids Logistics 50% March 2019 177 203 Total $ 22,719 $ 23,182 (1) Ownership interest percentages are at March 31, 2021. (2) This is an investment with a related party. See Note 13 for a further discussion.
Schedule of other noncurrent assets	Other noncurrent assets consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) Loan receivable (1) $ 2,962 $ 5,374 Line fill (2) 28,110 25,763 Minimum shipping fees - pipeline commitments (3) 13,171 17,443 Other 6,490 14,557 Total $ 50,733 $ 63,137 (1) Amounts at March 31, 2021 and 2020 represent the noncurrent portion of a loan receivable, net of an allowance for an expected credit loss, with a former related party. In addition, the amount at March 31, 2020 represents the noncurrent portion of a loan receivable associated with our interest in the construction of a natural gas liquids loading/unloading facility (the “Facility”) that is utilized by a third party. The third party filed for Chapter 11 bankruptcy in July 2019. For a further discussion, see Note 18. (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, 2021, line fill consisted of 423,978 barrels of crude oil. At March 31, 2020, line fill consisted of 335,069 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). During the three months ended March 31, 2020, we recorded an impairment of $7.7 million primarily due to adjusting the cost basis of pipeline line fill to the market price of propane as of March 31, 2020. (3) Represents the noncurrent portion of minimum shipping fees paid in excess of volumes shipped, or deficiency credits, for one contract with a crude oil pipeline operator. This amount can be recovered when volumes shipped exceed the minimum monthly volume commitment (see Note 9). As of March 31, 2021, the deficiency credit was $17.4 million, of which $4.2 million is recorded within prepaid expenses and other current assets in our consolidated balance sheet.
Schedule of accrued expenses and other payables	Accrued expenses and other payables consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) Accrued interest $ 56,299 $ 39,803 Accrued compensation and benefits 41,456 29,990 Derivative liabilities 21,562 17,777 Excise and other tax liabilities 10,970 9,941 Contingent consideration liability (1) 3,083 102,419 Product exchange liabilities 1,188 1,687 Other 35,842 30,445 Total $ 170,400 $ 232,062

(Loss) Income Per Common Unit (

(Loss) Income Per Common Unit (Tables)	12 Months Ended
	Mar. 31, 2021
Earnings Per Unit [Abstract]
Schedule of (loss) income per common unit	Our (loss) income per common unit is as follows for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands, except unit and per unit amounts) Loss from continuing operations $ (637,418) $ (180,545) $ (79,455) Less: Continuing operations (income) loss attributable to noncontrolling interests (632) 1,773 20,206 Net loss from continuing operations attributable to NGL Energy Partners LP (638,050) (178,772) (59,249) Less: Distributions to preferred unitholders (1)(2) (93,364) (188,734) (111,936) Less: Continuing operations net loss allocated to general partner (3) 731 260 32 Net loss from continuing operations allocated to common unitholders $ (730,683) $ (367,246) $ (171,153) (Loss) income from discontinued operations, net of tax $ (1,769) $ (218,235) $ 418,850 Less: Discontinued operations loss attributable to redeemable noncontrolling interests — — 446 Less: Discontinued operations net loss (income) allocated to general partner (3) 2 218 (419) Net (loss) income from discontinued operations allocated to common unitholders $ (1,767) $ (218,017) $ 418,877 Net (loss) income allocated to common unitholders $ (732,450) $ (585,263) $ 247,724 Basic (loss) income per common unit Loss from continuing operations $ (5.67) $ (2.88) $ (1.39) (Loss) income from discontinued operations, net of tax $ (0.01) $ (1.71) $ 3.41 Net (loss) income $ (5.68) $ (4.59) $ 2.01 Diluted (loss) income per common unit Loss from continuing operations $ (5.67) $ (2.88) $ (1.39) (Loss) income from discontinued operations, net of tax $ (0.01) $ (1.71) $ 3.41 Net (loss) income $ (5.68) $ (4.59) $ 2.01 Basic weighted average common units outstanding 128,980,823 127,411,908 123,017,064 Diluted weighted average common units outstanding 128,980,823 127,411,908 123,017,064 (1) This amount includes distributions to preferred unitholders. The final accretion for the beneficial conversion of the 10.75% Class A Preferred Units (as defined herein) and the excess of the 10.75% Class A Preferred Units repurchase price over the carrying value of the units, as discussed further in Note 10, are included in the year ended March 31, 2020. (2) Includes cumulative dividends for the quarter ended March 31, 2021 which were earning but not declared or paid (see Note 10). (3) Net loss (income) allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights.
Schedule of weighted average number of common units	The following table presents our calculation of basic and diluted weighted average common units outstanding for the periods indicated: Year Ended March 31, 2021 2020 2019 Weighted average common units outstanding during the period: Common units - Basic 128,980,823 127,411,908 123,017,064 Common units - Diluted 128,980,823 127,411,908 123,017,064 For the years ended March 31, 2021, 2020 and 2019, all potential common units or convertible securities were considered antidilutive.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Mar. 31, 2021
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 2021 2020 (in years) (in thousands) Natural gas liquids terminal and storage assets 2 - 30 $ 319,554 $ 314,694 Pipeline and related facilities 30 - 40 264,405 244,751 Vehicles and railcars 3 - 25 126,088 123,937 Water treatment facilities and equipment 3 - 30 1,930,437 1,525,859 Crude oil tanks and related equipment 2 - 30 238,924 234,143 Barges and towboats 5 - 30 137,386 125,162 Information technology equipment 3 - 7 50,220 34,261 Buildings and leasehold improvements 3 - 40 165,679 151,690 Land 100,352 91,446 Tank bottoms and line fill (1) 20,237 20,346 Other 3 - 20 15,054 14,627 Construction in progress 114,796 499,707 3,483,132 3,380,623 Accumulated depreciation (776,279) (529,068) Net property, plant and equipment $ 2,706,853 $ 2,851,555 (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.
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, 2021 2020 2019 (in thousands) Depreciation expense $ 190,204 $ 132,791 $ 101,515 Capitalized interest expense $ 2,778 $ 650 $ 482 Amounts in the table above do not include depreciation expense and capitalized interest related to TransMontaigne Product Services, LLC (“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 19).
Schedule of (gain) loss on disposal or impairment 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 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, 2021 2020 2019 (in thousands) Water Solutions $ 36,492 $ 22,491 $ 3,067 Crude Oil Logistics 1,766 36 3,489 Liquids Logistics 3,350 (30) 993 Corporate 228 — — Total $ 41,836 $ 22,497 $ 7,549 During the year ended March 31, 2021, the following transactions were recorded within our Water Solutions segment: • An impairment charge of $30.6 million to write down the value of an asset group due to a decline in producer activity, resulting in lower disposal volumes. See Note 7 for a discussion of the impairment of intangible assets within this asset group. • An impairment charge of $11.9 million to write down the value of certain inactive saltwater disposal facilities that we do not expect to bring back online. • A net loss of $6.7 million related to write-down or write off of certain assets, including facilities damaged by lightning strikes and abandoned projects, and the sale of certain other miscellaneous assets. • A gain of $12.8 million related to the sale of certain permits, land and a saltwater disposal facility (see Note 18). During the year ended March 31, 2020, the following transactions were recorded within our Water Solutions segment: • An impairment charge of $13.5 million to write down the value of certain inactive saltwater disposal facilities. • A net loss of $9.0 million related to write-down or write off of certain assets, including abandoned projects, and the sale of certain other miscellaneous assets.

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Mar. 31, 2021
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): Water Crude Oil Liquids Logistics Total (in thousands) Balances at March 31, 2019 $ 410,139 $ 579,846 $ 120,471 $ 1,110,456 Revisions to acquisition accounting 4,755 — (2,103) 2,652 Acquisitions 129,764 — 715 130,479 Impairment (250,000) — — (250,000) Balances at March 31, 2020 294,658 579,846 119,083 993,587 Revisions to acquisition accounting (Note 4) (11,348) — — (11,348) Impairment — (237,800) — (237,800) Balances at March 31, 2021 $ 283,310 $ 342,046 $ 119,083 $ 744,439

Intangible Assets (Tables)

Intangible Assets (Tables)	12 Months Ended
	Mar. 31, 2021
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, 2021 March 31, 2020 Description Amortizable Lives Gross Carrying Accumulated Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 1,318,638 $ (450,639) $ 867,999 $ 1,435,573 $ (445,250) $ 990,323 Customer commitments 10 - 25 192,000 (13,440) 178,560 502,000 (111,677) 390,323 Pipeline capacity rights 30 7,799 (1,907) 5,892 7,799 (1,647) 6,152 Rights-of-way and easements 1 - 45 90,703 (9,270) 81,433 89,476 (6,506) 82,970 Water rights 13 - 30 100,369 (14,454) 85,915 100,937 (8,441) 92,496 Executory contracts and other agreements 5 - 30 48,709 (21,300) 27,409 48,570 (18,210) 30,360 Non-compete agreements 2 - 24 12,100 (6,102) 5,998 12,723 (4,735) 7,988 Debt issuance costs (1) 2 - 5 9,558 (406) 9,152 44,051 (34,983) 9,068 Total amortizable 1,779,876 (517,518) 1,262,358 2,241,129 (631,449) 1,609,680 Non-amortizable: Trade names 255 — 255 2,800 — 2,800 Total $ 1,780,131 $ (517,518) $ 1,262,613 $ 2,243,929 $ (631,449) $ 1,612,480 (1) Includes debt issuance costs related to the ABL Facility (as defined herein), Revolving Credit Facility (as defined herein) and the Sawtooth credit agreement. Debt issuance costs related to fixed-rate notes, Bridge Term Credit Agreement (as defined herein) and Term Credit Agreement (as defined herein) are reported as a reduction of the carrying amount of long-term debt.
Schedule of indefinite-lived intangible assets	Our intangible assets consist of the following at the dates indicated: March 31, 2021 March 31, 2020 Description Amortizable Lives Gross Carrying Accumulated Net Gross Carrying Accumulated Net (in years) (in thousands) Amortizable: Customer relationships 3 - 30 $ 1,318,638 $ (450,639) $ 867,999 $ 1,435,573 $ (445,250) $ 990,323 Customer commitments 10 - 25 192,000 (13,440) 178,560 502,000 (111,677) 390,323 Pipeline capacity rights 30 7,799 (1,907) 5,892 7,799 (1,647) 6,152 Rights-of-way and easements 1 - 45 90,703 (9,270) 81,433 89,476 (6,506) 82,970 Water rights 13 - 30 100,369 (14,454) 85,915 100,937 (8,441) 92,496 Executory contracts and other agreements 5 - 30 48,709 (21,300) 27,409 48,570 (18,210) 30,360 Non-compete agreements 2 - 24 12,100 (6,102) 5,998 12,723 (4,735) 7,988 Debt issuance costs (1) 2 - 5 9,558 (406) 9,152 44,051 (34,983) 9,068 Total amortizable 1,779,876 (517,518) 1,262,358 2,241,129 (631,449) 1,609,680 Non-amortizable: Trade names 255 — 255 2,800 — 2,800 Total $ 1,780,131 $ (517,518) $ 1,262,613 $ 2,243,929 $ (631,449) $ 1,612,480 (1) Includes debt issuance costs related to the ABL Facility (as defined herein), Revolving Credit Facility (as defined herein) and the Sawtooth credit agreement. Debt issuance costs related to fixed-rate notes, Bridge Term Credit Agreement (as defined herein) and Term Credit Agreement (as defined herein) are reported as a reduction of the carrying amount of long-term debt.
Schedule of amortization expense	Amortization expense is as follows for the periods indicated: Year Ended March 31, Recorded In 2021 2020 2019 (in thousands) Depreciation and amortization $ 127,023 $ 132,521 $ 110,458 Cost of sales 307 349 486 Interest expense 5,572 5,462 4,928 Operating expenses 247 286 — Total $ 133,149 $ 138,618 $ 115,872 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 19).
Schedule of expected amortization of intangible assets	Expected amortization of our intangible assets is as follows (in thousands): Year Ending March 31, 2022 $ 96,206 2023 78,510 2024 72,308 2025 67,807 2026 66,413 Thereafter 881,114 Total $ 1,262,358

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Mar. 31, 2021
Long-Term Debt
Schedule of long-term debt	Our long-term debt consists of the following at the dates indicated: March 31, 2021 March 31, 2020 Face Unamortized Book Face Unamortized Book (in thousands) Senior secured notes: 7.500% Notes due 2026 (“2026 Senior Secured Notes”) $ 2,050,000 $ (44,246) $ 2,005,754 $ — $ — $ — Asset-based revolving credit facility 4,000 — 4,000 — — — Senior unsecured notes: 7.500% Notes due 2023 (“2023 Notes”) 555,251 (3,564) 551,687 607,323 (5,405) 601,918 6.125% Notes due 2025 (“2025 Notes”) 380,020 (3,297) 376,723 387,320 (4,217) 383,103 7.500% Notes due 2026 (“2026 Notes”) 338,402 (4,378) 334,024 450,000 (6,975) 443,025 Revolving credit facility: Expansion capital borrowings — — — 1,120,000 — 1,120,000 Working capital borrowings — — — 350,000 — 350,000 Bridge term credit agreement — — — 250,000 (3,198) 246,802 Other long-term debt 49,095 (70) 49,025 4,683 — 4,683 3,376,768 (55,555) 3,321,213 3,169,326 (19,795) 3,149,531 Less: Current maturities 2,183 — 2,183 4,683 — 4,683 Long-term debt $ 3,374,585 $ (55,555) $ 3,319,030 $ 3,164,643 $ (19,795) $ 3,144,848 (1) Debt issuance costs related to the ABL Facility, the Sawtooth credit agreement (included in other long-term debt) and the Revolving Credit Facility are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt.
Schedule of maturities of long-term debt	The scheduled maturities of our long-term debt are as follows at March 31, 2021: Year Ending March 31, 2026 Senior Secured Notes ABL Facility Senior Unsecured Notes Other Total (in thousands) 2022 $ — $ — $ — $ 2,184 $ 2,184 2023 — — — 7,585 7,585 2024 — — 555,251 2,816 558,067 2025 — — 380,020 3,068 383,088 2026 2,050,000 4,000 — 3,343 2,057,343 Thereafter — — 338,402 30,099 368,501 Total $ 2,050,000 $ 4,000 $ 1,273,673 $ 49,095 $ 3,376,768
Schedule of future amortization expense of debt issuance costs	Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2022 $ 12,247 2023 12,247 2024 11,677 2025 10,802 2026 8,529 Thereafter 53 Total $ 55,555
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, 2021 2020 2019 (in thousands) 2019 Notes Notes repurchased $ — $ — $ 25,419 Cash paid (excluding payments of accrued interest) $ — $ — $ 25,406 Loss on early extinguishment of debt (1) $ — $ — $ (34) 2023 Notes Notes repurchased $ 52,072 $ — $ 8,624 Cash paid (excluding payments of accrued interest) $ 33,566 $ — $ 8,575 Gain (loss) on early extinguishment of debt (2) $ 18,096 $ — $ (63) 2025 Notes Notes repurchased $ 7,300 $ 1,815 $ — Cash paid (excluding payments of accrued interest) $ 3,647 $ 454 $ — Gain on early extinguishment of debt (3) $ 3,575 $ 1,341 $ — 2026 Notes Notes repurchased $ 111,598 $ — $ — Cash paid (excluding payments of accrued interest) $ 78,583 $ — $ — Gain on early extinguishment of debt (4) $ 31,463 $ — $ — (1) Loss on 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 less than $0.1 million. The loss is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statement of operations. (2) Gain (loss) on early extinguishment of debt for the 2023 Notes during the years ended March 31, 2021 and 2019 is inclusive of the write off of debt issuance costs of $0.4 million and $0.1 million, respectively. The gain (loss) is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statements of operations. (3) Gain on early extinguishment of debt for the 2025 Notes during the years ended March 31, 2021 and 2020 is inclusive of the write off of debt issuance costs of $0.1 million and less than $0.1 million, respectively. The gain is reported within (loss) gain on early extinguishment of liabilities, net within our consolidated statements of operations. (4) Gain on early extinguishment of debt for the 2026 Notes during the year ended March 31, 2021 is inclusive of the write off of debt issuance costs of $1.6 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, 2021
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, 2019 $ 9,723 Liabilities incurred 1,643 Liabilities assumed in acquisitions 6,642 Liabilities settled (658) Accretion expense 1,066 Balance at March 31, 2020 18,416 Liabilities incurred 7,952 Liabilities associated with disposed assets (1) (22) Accretion expense 1,733 Balance at March 31, 2021 $ 28,079 (1) This amount relates to the sale of certain permits, land and a saltwater disposal facility (se e Note 18 ).
Schedule of future minimum payments under contractual commitments	The following table summarizes future minimum payments under these agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 10,074 2023 4,568 2024 4,568 2025 74 2026 55 Thereafter 275 Total $ 19,614
Schedule of future minimum payments under pipeline capacity agreements	The following table summarizes future minimum throughput payments under these agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 35,314 2023 35,314 2024 35,410 2025 30,897 Total $ 136,935
Schedule of outstanding purchase commitments	At March 31, 2021, we had the following commodity purchase commitments (in thousands): Crude Oil (1) Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Purchase Commitments: 2022 $ 93,285 1,515 $ 12,705 21,936 2023 — — 819 1,260 Total $ 93,285 1,515 $ 13,524 23,196 Index-Price Commodity Purchase Commitments: 2022 $ 3,038,806 54,413 $ 848,891 1,094,967 2023 1,835,567 35,588 2,848 4,774 2024 1,715,198 34,775 — — 2025 1,532,174 31,938 — — 2026 938,787 20,263 — — Total $ 9,060,532 176,977 $ 851,739 1,099,741 (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, 2021, we had the following commodity sale commitments (in thousands): Crude Oil Natural Gas Liquids Value Volume Value Volume Fixed-Price Commodity Sale Commitments: 2022 $ 93,464 1,515 $ 36,731 45,827 2023 — — 2,568 3,640 Total $ 93,464 1,515 $ 39,299 49,467 Index-Price Commodity Sale Commitments: 2022 $ 3,147,543 54,634 $ 546,242 558,346 2023 1,106,564 20,988 1,686 2,088 2024 1,058,526 21,045 — — 2025 1,024,037 20,988 — — 2026 484,326 10,242 — — Total $ 6,820,996 127,897 $ 547,928 560,434

Equity (Tables)

Equity (Tables)	12 Months Ended
	Mar. 31, 2021
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 Amount Paid to Amount Paid to (in thousands) (in thousands) 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 July 23, 2019 August 7, 2019 August 14, 2019 $ 0.3900 $ 49,217 $ 85 October 23, 2019 November 7, 2019 November 14, 2019 $ 0.3900 $ 49,936 $ 86 January 23, 2020 February 7, 2020 February 14, 2020 $ 0.3900 $ 50,056 $ 86 April 27, 2020 May 7, 2020 May 15, 2020 $ 0.2000 $ 25,754 $ 26 July 23, 2020 August 6, 2020 August 14, 2020 $ 0.2000 $ 25,754 $ 26 October 27, 2020 November 6, 2020 November 13, 2020 $ 0.1000 $ 12,877 $ 13
Service awards
Equity
Schedule of award activity	The following table summarizes the Service Award activity during the years ended March 31, 2021, 2020 and 2019: 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 Units granted 2,211,431 Units vested and issued (2,938,481) Units forfeited (209,925) Unvested Service Award units at March 31, 2020 1,371,425 Units granted 7,000 Units vested and issued (892,450) Units forfeited (39,000) Unvested Service Award units at March 31, 2021 446,975
Performance awards
Equity
Schedule of award activity	The following table summarizes the Performance Award activity during the year ended March 31, 2019: 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 two fiscal years: Date Declared Payment Date Amount Paid to Class A (in thousands) 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 three fiscal years: Date Declared Record Date Payment Date Amount Per Unit Amount Paid to Class B (in thousands) March 19, 2018 April 2, 2018 April 16, 2018 $ 0.5625 $ 4,725 June 19, 2018 July 2, 2018 July 16, 2018 $ 0.5625 $ 4,725 September 12, 2018 October 1, 2018 October 15, 2018 $ 0.5625 $ 4,725 December 17, 2018 December 31, 2018 January 15, 2019 $ 0.5625 $ 4,725 March 15, 2019 April 1, 2019 April 15, 2019 $ 0.5625 $ 4,725 June 14, 2019 July 1, 2019 July 15, 2019 $ 0.5625 $ 4,725 September 16, 2019 October 1, 2019 October 15, 2019 $ 0.5625 $ 7,079 December 16, 2019 December 31, 2019 January 15, 2020 $ 0.5625 $ 7,079 March 16, 2020 March 31, 2020 April 15, 2020 $ 0.5625 $ 7,079 June 15, 2020 June 30, 2020 July 15, 2020 $ 0.5625 $ 7,079 September 15, 2020 September 30, 2020 October 15, 2020 $ 0.5625 $ 7,079 December 17, 2020 January 1, 2021 January 15, 2021 $ 0.5625 $ 7,079
Class C Perpetual Preferred Units
Equity
Schedule of distributions declared	The following table summarizes distributions declared on our Class C Preferred Units during the last two fiscal years: Amount Paid to Class C Date Declared Record Date Payment Date Amount Per Unit Preferred Unitholders (in thousands) June 14, 2019 July 1, 2019 July 15, 2019 $ 0.5949 $ 1,071 September 16, 2019 October 1, 2019 October 15, 2019 $ 0.6016 $ 1,083 December 16, 2019 December 31, 2019 January 15, 2020 $ 0.6016 $ 1,083 March 16, 2020 March 31, 2020 April 15, 2020 $ 0.6016 $ 1,083 June 15, 2020 June 30, 2020 July 15, 2020 $ 0.6016 $ 1,083 September 15, 2020 September 30, 2020 October 15, 2020 $ 0.6016 $ 1,083 December 17, 2020 January 1, 2021 January 15, 2021 $ 0.6016 $ 1,083
Class D Preferred Units
Equity
Schedule of distributions declared	The following table summarizes cash distributions declared on our Class D Preferred Units during the last two fiscal years: Amount Paid to Class D Date Declared Record Date Payment Date Amount Per Unit Preferred Unitholders (in thousands) October 23, 2019 November 7, 2019 November 14, 2019 $ 11.25 $ 4,450 January 23, 2020 February 7, 2020 February 14, 2020 $ 11.25 $ 6,075 April 27, 2020 May 7, 2020 May 15, 2020 $ 11.25 $ 6,868 July 23, 2020 August 6, 2020 August 14, 2020 $ 11.25 $ 6,946 October 27, 2020 November 6, 2020 November 13, 2020 $ 26.01 $ 15,608 January 20, 2021 February 5, 2021 February 12, 2021 $ 26.01 $ 15,608

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Mar. 31, 2021
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, 2021 March 31, 2020 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 12,312 $ (17,857) $ 64,037 $ (2,235) Level 2 measurements 37,520 (24,474) 25,217 (17,635) 49,832 (42,331) 89,254 (19,870) Netting of counterparty contracts (1) (12,648) 12,648 (2,282) 2,282 Net cash collateral provided (held) 2,660 5,543 (50,104) (370) Commodity derivatives $ 39,844 $ (24,140) $ 36,868 $ (17,958) (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, 2021 2020 (in thousands) Prepaid expenses and other current assets $ 39,844 $ 36,868 Accrued expenses and other payables (21,562) (17,777) Other noncurrent liabilities (2,578) (181) Net commodity derivative asset $ 15,704 $ 18,910
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, 2021: Crude oil fixed-price (1) April 2021–December 2023 (1,850) $ (5,414) Propane fixed-price (1) April 2021–December 2023 (195) 2,188 Refined products fixed-price (1) April 2021–January 2022 (503) 1,928 Butane fixed-price (1) April 2021–March 2022 (753) (3,764) Other April 2021–June 2022 12,563 7,501 Net cash collateral provided 8,203 Net commodity derivative asset $ 15,704 At March 31, 2020: Crude oil fixed-price (1) April 2020–December 2021 (2,252) $ 41,721 Propane fixed-price (1) April 2020–December 2021 415 (738) Refined products fixed-price (1) April 2020–January 2021 (26) 27,401 Other April 2020–March 2022 1,000 69,384 Net cash collateral held (50,474) Net commodity derivative asset $ 18,910
Schedule of net (losses) gains from commodity derivatives	The following table summarizes the net (losses) gains 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, 2021 $ (83,578) 2020 $ 85,941 2019 $ 10,817 Amounts in the table above do not include net (losses) gains 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 19).
Schedule of fair value estimates of fixed-rate notes	The following table provides fair values estimates of our fixed-rate notes at March 31, 2021 (in thousands): Senior Secured Notes: 2026 Senior Secured Notes $ 2,114,917 Senior Unsecured Notes: 2023 Notes $ 535,817 2025 Notes $ 322,384 2026 Notes $ 287,924

Segments (Tables)

Segments (Tables)	12 Months Ended
	Mar. 31, 2021
Segment Reporting [Abstract]
Schedule of certain information related to results of operations by segment	The following table summarizes revenues related to our segments for the periods indicated. During the three months ended March 31, 2021, we changed the name of our Liquids and Refined Products segment to Liquids Logistics. 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, 2021 2020 2019 (in thousands) Revenues: Water Solutions: Topic 606 revenues Disposal service fees $ 317,640 $ 330,877 $ 217,545 Sale of recovered crude oil 28,599 59,445 72,678 Sale of brackish non-potable water 10,554 11,676 2,404 Other service revenues 14,193 20,061 9,017 Non-Topic 606 revenues — — 42 Total Water Solutions revenues 370,986 422,059 301,686 Crude Oil Logistics: Topic 606 revenues Crude oil sales 1,574,699 2,383,812 3,011,355 Crude oil transportation and other 142,233 170,138 148,738 Non-Topic 606 revenues 11,355 13,991 12,598 Elimination of intersegment sales (6,651) (18,174) (36,056) Total Crude Oil Logistics revenues 1,721,636 2,549,767 3,136,635 Liquids Logistics: Topic 606 revenues Refined products sales 1,123,963 2,399,642 2,535,243 Propane sales 1,023,479 842,400 1,169,117 Butane sales 516,358 562,053 628,063 Other product sales 373,707 484,373 592,889 Service revenues 22,270 37,938 26,655 Non-Topic 606 revenues 79,442 289,713 320,798 Elimination of intersegment sales (6,073) (4,983) (23,291) Total Liquids Logistics revenues 3,133,146 4,611,136 5,249,474 Corporate and Other: Non-Topic 606 revenues 1,255 1,038 1,362 Total Corporate and Other revenues 1,255 1,038 1,362 Total revenues $ 5,227,023 $ 7,584,000 $ 8,689,157 The following table summarizes depreciation and amortization expense (including amortization expense recorded within interest expense, cost of sales and operating expenses in Note 7 and Note 8) and operating income (loss) by segment for the periods indicated. Year Ended March 31, 2021 2020 2019 (in thousands) Depreciation and Amortization: Water Solutions $ 222,354 $ 163,874 $ 108,162 Crude Oil Logistics 60,874 70,759 74,245 Liquids Logistics 29,503 28,279 27,034 Corporate and Other 18,469 13,936 12,233 Total depreciation and amortization $ 331,200 $ 276,848 $ 221,674 Operating Income (Loss): Water Solutions $ (92,720) $ (173,064) $ 210,525 Crude Oil Logistics (304,330) 117,768 (7,379) Liquids Logistics 70,441 142,411 9,288 Corporate and Other (64,144) (90,447) (85,706) Total operating (loss) income $ (390,753) $ (3,332) $ 126,728
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, 2021 2020 2019 (in thousands) Water Solutions $ 66,649 $ 2,076,866 $ 567,637 Crude Oil Logistics 9,933 28,828 28,039 Liquids Logistics 31,172 19,753 72,717 Corporate and Other 11,953 7,968 1,819 Total $ 119,707 $ 2,133,415 $ 670,212 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 (see Note 19).
Schedule of long-lived assets (consisting of property, plant and equipment, intangible assets, operating lease right-of-use assets and goodwill) and total assets by segment	The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, operating lease right-of-use assets and goodwill) and total assets by segment at the dates indicated: March 31, 2021 2020 (in thousands) Long-lived assets, net: Water Solutions $ 3,104,450 $ 3,382,727 Crude Oil Logistics 1,090,578 1,567,503 Liquids Logistics (1) 626,221 654,530 Corporate and Other 44,802 33,570 Total $ 4,866,051 $ 5,638,330 (1) Includes $20.9 million and $25.9 million of non-US long-lived assets at March 31, 2021 and 2020, respectively. March 31, 2021 2020 (in thousands) Total assets: Water Solutions $ 3,204,850 $ 3,539,328 Crude Oil Logistics 1,665,005 1,886,211 Liquids Logistics (1) 1,003,370 972,684 Corporate and Other 74,116 100,513 Total $ 5,947,341 $ 6,498,736 (1) Includes $37.9 million and $37.8 million of non-US total assets at March 31, 2021 and 2020, respectively.

Transactions with Affiliates (T

Transactions with Affiliates (Tables)	12 Months Ended
	Mar. 31, 2021
Related Party Transactions [Abstract]
Summary of purchase and sales transactions of products and services	The following table summarizes our related party transactions for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands) Sales to WPX $ 39,129 $ 48,222 $ 28,026 Purchases from WPX (1) $ 216,487 $ 313,578 $ 329,525 Sales to SemGroup $ 458 $ 1,114 Purchases from SemGroup $ — $ 4,395 Sales to entities affiliated with management $ 18,402 $ 8,367 $ 21,385 Purchases from entities affiliated with management $ 1,239 $ 3,799 $ 4,382 Sales to equity method investees $ — $ 203 $ — Purchases from equity method investees $ 3,249 $ 2,120 $ —
Schedule of accounts receivable from affiliates	Accounts receivable from affiliates consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) NGL Energy Holdings LLC $ 8,245 $ 7,781 WPX — 3,563 Entities affiliated with management 728 151 Equity method investees 462 1,439 Total $ 9,435 $ 12,934
Schedule of accounts payable to affiliates	Accounts payable to affiliates consist of the following at the dates indicated: March 31, 2021 2020 (in thousands) WPX $ — $ 17,039 Entities affiliated with management 12 149 Equity method investees 107 529 Total $ 119 $ 17,717

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Mar. 31, 2021
Revenue from Contract with Customer [Abstract]
Schedule of amount and timing of remaining performance obligations	The following table summarizes the amount and timing of revenue recognition for such contracts at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 111,966 2023 101,702 2024 78,241 2025 56,288 2026 17,732 Thereafter 5,667 Total $ 371,596
Schedule of contract assets and liabilities	The following tables summarize the balances of our contract assets and liabilities at the dates indicated: March 31, 2021 March 31, 2020 (in thousands) Accounts receivable from contracts with customers $ 436,682 $ 372,930 Contract liabilities balance at March 31, 2020 $ 19,536 Payment received and deferred 36,861 Payment recognized in revenue (45,234) Contract liabilities balance at March 31, 2021 $ 11,163

Leases (Tables)

Leases (Tables)	12 Months Ended
	Mar. 31, 2021
Leases [Abstract]
Schedule of components for lease expense	The following table summarizes the components of our lease expense for the periods indicated: Year Ended March 31, 2021 2020 (in thousands) Operating lease expense $ 69,031 $ 72,340 Variable lease expense 18,871 19,158 Short-term lease expense 1,217 799 Total lease expense $ 89,119 $ 92,297 Amounts in the table above do not include lease expense related to TPSL and Gas Blending, as these amounts have been classified within discontinued operations within our consolidated statement of operations for all periods presented (see Note 19).
Schedule of maturities of operating lease obligations	The following table summarizes maturities of our operating lease obligations at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 53,842 2023 41,395 2024 26,589 2025 15,349 2026 7,406 Thereafter 50,804 Total lease payments 195,385 Less imputed interest (44,678) Total operating lease obligations $ 150,707
Schedule of supplemental cash flow and non-cash information for operating leases	The following table summarizes supplemental cash flow and non-cash information related to our operating leases for the periods indicated: Year Ended March 31, 2021 2020 (1) (in thousands) Cash paid for amounts included in the measurement of operating lease obligations $ 68,141 $ 101,678 Operating lease right-of-use assets obtained in exchange for operating lease obligations $ 33,579 $ 598,734 (1) Amounts include the leases and activity for TPSL and Gas Blending which were sold during the year ended March 31, 2020 (see Note 19).
Schedule of future minimum lease payments receivable under contractual commitments	The following table summarizes future minimum lease payments receivable under various noncancelable operating lease agreements at March 31, 2021 (in thousands): Year Ending March 31, 2022 $ 11,944 2023 8,959 2024 4,817 2025 690 2026 416 Thereafter 800 Total $ 27,626

Allowance for Current Expecte_3

Allowance for Current Expected Credit Loss (Tables)	12 Months Ended
	Mar. 31, 2021
Credit Loss [Abstract]
Schedule of allowance for expected credit losses for accounts receivable - trade	The following table summarizes changes in our expected credit loss allowance for accounts receivable - trade for the periods indicated: Year Ended March 31, 2021 2020 (1) 2019 (1) (in thousands) Balance at beginning of year $ 4,540 $ 4,016 $ 3,851 Cumulative effect adjustment 433 — — Current period provision for expected credit losses 319 1,202 381 Write-offs charged against the allowance (3,100) (678) (216) Balance at end of year $ 2,192 $ 4,540 $ 4,016 (1) We adopted ASU No. 2016-13 as of April 1, 2020. The allowance reported for the years ended March 31, 2020 and 2019 has not been changed from its previous presentation.
Schedule of allowance for expected credit losses for notes receivable and other	The following table summarizes changes in our expected credit loss allowance for notes receivable and other for the period indicated: Year Ended March 31, 2021 (1) (in thousands) Balance at beginning of year $ — Cumulative effect adjustment 680 Write-offs charged against the allowance (222) Balance at end of year $ 458 (1) We adopted ASU No. 2016-13 as of April 1, 2020. An allowance had not been established for notes receivable and other prior to the adoption of ASU No. 2016-13.

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Mar. 31, 2021
Discontinued Operations and Disposal Groups [Abstract]
Schedule of results of operations of discontinued operations	The following table summarizes the results of operations from discontinued operations for the periods indicated: Year Ended March 31, 2021 2020 2019 (in thousands) Revenues $ 16,198 $ 12,186,862 $ 15,398,608 Cost of sales 16,556 12,193,307 15,338,614 Operating expenses 290 6,997 37,348 General and administrative expense — 56 2,716 Depreciation and amortization — 749 9,593 Loss (gain) on disposal or impairment of assets, net (1) 1,174 203,990 (407,608) Operating (loss) income from discontinued operations (1,822) (218,237) 417,945 Equity in earnings of unconsolidated entities — — 1,183 Interest expense — (111) (126) Other income, net — 133 837 (Loss) income from discontinued operations before taxes (2) (1,822) (218,215) 419,839 Income tax benefit (expense) 53 (20) (989) (Loss) income from discontinued operations, net of tax $ (1,769) $ (218,235) $ 418,850 (1) Amount for the year ended March 31, 2021 includes a loss of $1.0 million on the sale of Gas Blending and $0.2 million on the sale of TPSL. Amount for the year ended March 31, 2020 includes a loss of $182.1 million on the sale of TPSL, a loss of $6.3 million on the sale of Mid-Con, a loss of $14.5 million on the sale of Gas Blending and a loss of $1.0 million on the sale of virtually all of our remaining Retail Propane segment to Superior on July 10, 2018. 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 LPG on March 30, 2018 related to a working capital adjustment. (2) Amount for the year ended March 31, 2019 includes a loss attributable to redeemable noncontrolling interests of $0.4 million.

Nature of Operations and Orga_2

Nature of Operations and Organization (Details)	Mar. 31, 2021
Liquids Logistics
Business Acquisition
Number of owned terminals	28

Significant Accounting Polici_4

Significant Accounting Policies - Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Minimum percentage of qualifying income of non-taxable subsidiaries	90.00%
Deferred tax liability	$ 45.8	$ 56.4
Deferred tax benefit	$ 4.7	$ 2.9
Effective tax rate	39.70%	27.80%

Significant Accounting Polici_5

Significant Accounting Policies - Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Mar. 31, 2020
Inventories
Crude oil	$ 64,916	$ 18,201
Propane	45,521	25,163
Butane	19,189	9,619
Biodiesel	16,169	8,195
Ethanol	3,056	1,834
Diesel	2,252	2,414
Other	7,364	4,208
Total	$ 158,467	$ 69,634

Significant Accounting Polici_6

Significant Accounting Policies - Investments in Unconsolidated Entities (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Mar. 31, 2020	Jun. 30, 2018
Investments in Unconsolidated Entities
Ownership interest			50.00%
Carrying value	$ 22,719	$ 23,182
Cumulative earnings from unconsolidated entities	5,100
Cumulative distributions received from unconsolidated entities	$ 6,800
Water Services and Land Company No. 1 | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest	50.00%
Carrying value	$ 15,832	16,607
Water Services and Land Company No. 2 | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest	50.00%
Carrying value	$ 2,284	2,092
Water Services and Land Company No. 3 | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest	10.00%
Carrying value	$ 3,254	3,384
Aircraft Company | Corporate and Other | Operating segment
Investments in Unconsolidated Entities
Carrying value	$ 748	447
Water Services Company | Water solutions | Operating segment
Investments in Unconsolidated Entities
Ownership interest	50.00%
Carrying value	$ 424	449
Natural Gas Liquids Terminal Company | Liquids Logistics | Operating segment
Investments in Unconsolidated Entities
Ownership interest	50.00%
Carrying value	$ 177	$ 203
KAIR2014 LLC | Aircraft Company | Corporate and Other | Operating segment
Investments in Unconsolidated Entities
Ownership interest	50.00%

Significant Accounting Polici_7

Significant Accounting Policies - Other Noncurrent Assets (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2020USD ($)bbl	Mar. 31, 2021USD ($)bbl
Other Assets, Noncurrent [Abstract]
Loan receivable	$ 5,374	$ 2,962
Line fill	25,763	28,110
Minimum shipping fees - pipeline commitments, noncurrent	17,443	13,171
Other	14,557	6,490
Total	$ 63,137	$ 50,733
Other Noncurrent Assets
Number of contracts		1
Minimum shipping fees - pipeline commitments, total		$ 17,400
Minimum shipping fees - pipeline commitments, current		$ 4,200
Crude oil
Other Noncurrent Assets
Number of barrels of product | bbl	335,069	423,978
Propane sales
Other Noncurrent Assets
Number of barrels of product | bbl	262,000
Line fill impairment	$ 7,700

Significant Accounting Polici_8

Significant Accounting Policies - Accrued Expenses and Other Payables (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Mar. 31, 2020
Accounting Policies [Abstract]
Accrued interest	$ 56,299	$ 39,803
Accrued compensation and benefits	41,456	29,990
Derivative liabilities	21,562	17,777
Excise and other tax liabilities	10,970	9,941
Contingent consideration liability (1)	3,083	102,419
Product exchange liabilities	1,188	1,687
Other	35,842	30,445
Total	170,400	$ 232,062
Mesquite
Business Acquisition
Total contingent consideration liability	$ 100,000

Significant Accounting Polici_9

Significant Accounting Policies - Recent Accounting Pronouncements (Details) $ in Millions	Apr. 01, 2020USD ($)
Accounting Changes and Error Corrections [Abstract]
Cumulative effect adjustment for adoption of ASU 2016-13	$ 1.1

(Loss) Income Per Common Unit_2

(Loss) Income Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 21, 2016	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
(Loss) Income Per Common Unit
Loss from continuing operations		$ (637,418)	$ (180,545)	$ (79,455)
Less: Continuing operations (income) loss attributable to noncontrolling interests		(632)	1,773	20,206
Net loss from continuing operations attributable to NGL Energy Partners LP		(638,050)	(178,772)	(59,249)
Less: Distributions to preferred unitholders (1)(2)		(93,364)	(188,734)	(111,936)
Less: Continuing operations net loss allocated to general partner (3)		731	260	32
NET LOSS FROM CONTINUING OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)		(730,683)	(367,246)	(171,153)
(Loss) income from discontinued operations, net of tax		(1,769)	(218,235)	418,850
LESS: NET LOSS ATTRIBUTABLE TO REDEEMABLE NONCONTROLLING INTERESTS		0	0	446
Less: Discontinued operations net loss (income) allocated to general partner (3)		2	218	(419)
NET (LOSS) INCOME FROM DISCONTINUED OPERATIONS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)		(1,767)	(218,017)	418,877
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)		$ (732,450)	$ (585,263)	$ 247,724
BASIC (LOSS) INCOME PER COMMON UNIT
Loss from continuing operations		$ (5.67)	$ (2.88)	$ (1.39)
(Loss) income from discontinued operations, net of tax		(0.01)	(1.71)	3.41
Net (Loss) Income		(5.68)	(4.59)	2.01
DILUTED (LOSS) INCOME PER COMMON UNIT
Loss from continuing operations		(5.67)	(2.88)	(1.39)
(Loss) income from discontinued operations, net of tax		(0.01)	(1.71)	3.41
Net (Loss) Income		$ (5.68)	$ (4.59)	$ 2.01
Basic weighted average common units outstanding (in units)		128,980,823	127,411,908	123,017,064
Diluted weighted average common units outstanding (in units)		128,980,823	127,411,908	123,017,064
Oaktree Capital Management L.P. | Class A Convertible Preferred Units
DILUTED (LOSS) INCOME PER COMMON UNIT
Preferred units dividend rate	10.75%
Common units
BASIC (LOSS) INCOME PER COMMON UNIT
Loss from continuing operations		$ (5.67)	$ (2.88)	$ (1.39)
(Loss) income from discontinued operations, net of tax		(0.01)	(1.71)	3.41
Net (Loss) Income		(5.68)	(4.59)	2.01
DILUTED (LOSS) INCOME PER COMMON UNIT
Loss from continuing operations		(5.67)	(2.88)	(1.39)
(Loss) income from discontinued operations, net of tax		(0.01)	(1.71)	3.41
Net (Loss) Income		$ (5.68)	$ (4.59)	$ 2.01
Basic weighted average common units outstanding (in units)		128,980,823	127,411,908	123,017,064
Diluted weighted average common units outstanding (in units)		128,980,823	127,411,908	123,017,064

Acquisitions - Kalkaska (Detail

Acquisitions - Kalkaska (Details) $ in Millions	1 Months Ended
	Mar. 31, 2021USD ($)
Business Combinations [Abstract]
Number of miles of pipeline acquired	225
Payments to acquire assets	$ 18.2

Acquisitions - Hillstone (Detai

Acquisitions - Hillstone (Details) - Hillstone $ in Millions	12 Months Ended
	Mar. 31, 2021USD ($)
Business Acquisition
Purchase accounting adjustment, current assets	$ (0.7)
Purchase accounting adjustment, current liabilities	(5.1)
Purchase accounting adjustment, deferred tax liabilities	(6)
Purchase price decrease	$ (0.9)

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Property, Plant and Equipment
Gross property, plant and equipment	$ 3,483,132	$ 3,380,623
Accumulated depreciation	(776,279)	(529,068)
Net property, plant and equipment	2,706,853	2,851,555
Depreciation expense	190,204	132,791	$ 101,515
Capitalized interest expense	2,778	650	482
(Gain) loss on sales and write-downs of certain assets	41,836	22,497	7,549
Gain on disposal or impairment of assets, net	(475,436)	(261,786)	(34,296)
Water solutions
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	36,492	22,491	3,067
Asset impairment charges	30,600
Gain on disposal or impairment of assets, net	(12,800)
Water solutions | Inactive saltwater disposal facilities
Property, Plant and Equipment
Asset impairment charges	11,900	13,500
Water solutions | Write down of certain water assets
Property, Plant and Equipment
Asset impairment charges	6,700	9,000
Crude oil logistics
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	1,766	36	3,489
Liquids Logistics
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	3,350	(30)	993
Corporate and Other
Property, Plant and Equipment
(Gain) loss on sales and write-downs of certain assets	228	0	$ 0
Natural gas liquids terminal and storage assets
Property, Plant and Equipment
Gross property, plant and equipment	$ 319,554	314,694
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	$ 264,405	244,751
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	$ 126,088	123,937
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	$ 1,930,437	1,525,859
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	$ 238,924	234,143
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	$ 137,386	125,162
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	$ 50,220	34,261
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	$ 165,679	151,690
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	$ 100,352	91,446
Tank bottoms and line fill
Property, Plant and Equipment
Gross property, plant and equipment	20,237	20,346
Other
Property, Plant and Equipment
Gross property, plant and equipment	$ 15,054	14,627
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	$ 114,796	$ 499,707

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2021	Mar. 31, 2020
Goodwill [Roll Forward]
Goodwill at the beginning of the period			$ 993,587	$ 1,110,456
Revisions to acquisition accounting (Note 4)			(11,348)	2,652
Acquisitions				130,479
Impairment			(237,800)	(250,000)
Goodwill at the end of the period	$ 993,587	$ 1,110,456	744,439	993,587
Water solutions
Goodwill [Roll Forward]
Goodwill at the beginning of the period			294,658	410,139
Revisions to acquisition accounting (Note 4)			(11,348)	4,755
Acquisitions				129,764
Impairment	(250,000)			(250,000)
Goodwill at the end of the period	294,658	410,139	283,310	294,658
Crude oil logistics
Goodwill [Roll Forward]
Goodwill at the beginning of the period			579,846	579,846
Impairment			(237,800)
Goodwill at the end of the period	579,846	579,846	342,046	579,846
Liquids Logistics
Goodwill [Roll Forward]
Goodwill at the beginning of the period			119,083	120,471
Revisions to acquisition accounting (Note 4)				(2,103)
Acquisitions				715
Impairment		(66,200)
Goodwill at the end of the period	$ 119,083	$ 120,471	$ 119,083	$ 119,083

Goodwill Impairment (Details)

Goodwill Impairment (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Mar. 31, 2021	Mar. 31, 2020	Jan. 01, 2020	Jan. 01, 2019
Goodwill
Goodwill impairment		$ 237,800	$ 250,000
Water solutions
Goodwill
Reporting unit percentage of fair value above carrying amount		3.00%
Reporting unit, percentage of fair value below carrying amount				7.30%
Goodwill impairment	$ 250,000		$ 250,000
Crude oil logistics
Goodwill
Reporting unit, percentage of fair value below carrying amount		17.00%
Goodwill impairment		$ 237,800
Sawtooth
Goodwill
Reporting unit, percentage of fair value below carrying amount					35.20%
Goodwill, impairment test, assumed per year increase in rental fees					7.00%
Goodwill, impairment test, discount rate					13.10%

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Amortizable
Finite-lived intangible assets, gross	$ 1,779,876	$ 2,241,129
Accumulated amortization	(517,518)	(631,449)
Total	1,262,358	1,609,680
Gross carrying amount of intangible assets	1,780,131	2,243,929
INTANGIBLE ASSETS, net of accumulated amortization	$ 1,262,613	1,612,480
Weighted average remaining amortization period for intangible assets	20 years 8 months 12 days
Trade names
Non-Amortizable
Indefinite-lived intangible assets	$ 255	2,800
Trade names | Water solutions
Non-Amortizable
Intangible asset impairment, indefinite-lived	2,500
Customer relationships
Amortizable
Finite-lived intangible assets, gross	1,318,638	1,435,573
Accumulated amortization	(450,639)	(445,250)
Total	867,999	990,323
Customer relationships | Water solutions
Amortizable
Intangible asset impairment	$ 39,200
Customer relationships | Minimum
Amortizable
Amortizable life	3 years
Customer relationships | Maximum
Amortizable
Amortizable life	30 years
Customer commitments
Amortizable
Finite-lived intangible assets, gross	$ 192,000	502,000
Accumulated amortization	(13,440)	(111,677)
Total	178,560	390,323
Customer commitments | Crude oil logistics
Amortizable
Intangible asset impairment	$ 145,800
Customer commitments | Minimum
Amortizable
Amortizable life	10 years
Customer commitments | Maximum
Amortizable
Amortizable life	25 years
Pipeline capacity rights
Amortizable
Amortizable life	30 years
Finite-lived intangible assets, gross	$ 7,799	7,799
Accumulated amortization	(1,907)	(1,647)
Total	5,892	6,152
Right-of-way and easements
Amortizable
Finite-lived intangible assets, gross	90,703	89,476
Accumulated amortization	(9,270)	(6,506)
Total	$ 81,433	82,970
Right-of-way and easements | Minimum
Amortizable
Amortizable life	1 year
Right-of-way and easements | Maximum
Amortizable
Amortizable life	45 years
Water rights
Amortizable
Finite-lived intangible assets, gross	$ 100,369	100,937
Accumulated amortization	(14,454)	(8,441)
Total	$ 85,915	92,496
Water rights | Minimum
Amortizable
Amortizable life	13 years
Water rights | Maximum
Amortizable
Amortizable life	30 years
Executory contracts and other agreements
Amortizable
Finite-lived intangible assets, gross	$ 48,709	48,570
Accumulated amortization	(21,300)	(18,210)
Total	$ 27,409	30,360
Executory contracts and other agreements | Minimum
Amortizable
Amortizable life	5 years
Executory contracts and other agreements | Maximum
Amortizable
Amortizable life	30 years
Non-compete agreements
Amortizable
Finite-lived intangible assets, gross	$ 12,100	12,723
Accumulated amortization	(6,102)	(4,735)
Total	$ 5,998	7,988
Non-compete agreements | Minimum
Amortizable
Amortizable life	2 years
Non-compete agreements | Maximum
Amortizable
Amortizable life	24 years
Debt issuance costs
Amortizable
Finite-lived intangible assets, gross	$ 9,558	44,051
Accumulated amortization	(406)	(34,983)
Total	9,152	$ 9,068
Debt issuance costs | Corporate and Other
Amortizable
Intangible asset impairment	$ 4,500
Debt issuance costs | Minimum
Amortizable
Amortizable life	2 years
Debt issuance costs | Maximum
Amortizable
Amortizable life	5 years

Intangible Assets - Amortizatio

Intangible Assets - Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Amortization related to intangible assets
Amortization expense	$ 133,149	$ 138,618	$ 115,872
Future amortization expense of intangible assets
2022	96,206
2023	78,510
2024	72,308
2025	67,807
2026	66,413
Thereafter	881,114
Total	1,262,358	1,609,680
Depreciation and amortization
Amortization related to intangible assets
Amortization expense	127,023	132,521	110,458
Cost of sales
Amortization related to intangible assets
Amortization expense	307	349	486
Interest expense
Amortization related to intangible assets
Amortization expense	5,572	5,462	4,928
Operating expenses
Amortization related to intangible assets
Amortization expense	$ 247	$ 286	$ 0

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($)	Mar. 31, 2021	Feb. 04, 2021	Mar. 31, 2020	Apr. 09, 2019	Feb. 22, 2017	Oct. 24, 2016	Jul. 09, 2014	Oct. 16, 2013
Long-Term Debt
Face amount	$ 3,376,768,000		$ 3,169,326,000
Face amount, current portion	2,183,000		4,683,000
Face amount, long-term	3,374,585,000		3,164,643,000
LONG-TERM DEBT, debt issuance costs	(55,555,000)		(19,795,000)
Debt issuance costs, current, net	0		0
Debt issuance costs, noncurrent, net	(55,555,000)		(19,795,000)
Book value	3,321,213,000		3,149,531,000
Book value, current	2,183,000		4,683,000
LONG-TERM DEBT, net of debt issuance costs and current maturities	3,319,030,000		3,144,848,000
7.5% Senior Secured Notes due 2026
Long-Term Debt
Fixed interest rate		7.50%
Face amount	2,050,000,000
LONG-TERM DEBT, debt issuance costs	(44,246,000)
Book value	2,005,754,000
Asset Based Credit Facility
Long-Term Debt
Face amount	4,000,000
LONG-TERM DEBT, debt issuance costs	0
Book value	4,000,000
5.125% Senior Notes due 2019
Long-Term Debt
Fixed interest rate							5.125%
6.875% Senior Notes due 2021
Long-Term Debt
Fixed interest rate								6.875%
7.5% Senior Notes due 2023
Long-Term Debt
Fixed interest rate						7.50%
Face amount	555,251,000		607,323,000
LONG-TERM DEBT, debt issuance costs	(3,564,000)		(5,405,000)
Book value	551,687,000		601,918,000
6.125% Senior Notes due 2025
Long-Term Debt
Fixed interest rate					6.125%
Face amount	380,020,000		387,320,000
LONG-TERM DEBT, debt issuance costs	(3,297,000)		(4,217,000)
Book value	376,723,000		383,103,000
7.5% Senior Notes due 2026
Long-Term Debt
Fixed interest rate				7.50%
Face amount	338,402,000		450,000,000
LONG-TERM DEBT, debt issuance costs	(4,378,000)		(6,975,000)
Book value	334,024,000		443,025,000
Bridge Term Credit Agreement
Long-Term Debt
Face amount			250,000,000
LONG-TERM DEBT, debt issuance costs			(3,198,000)
Book value			246,802,000
Other long-term debt
Long-Term Debt
Face amount	49,095,000		4,683,000
LONG-TERM DEBT, debt issuance costs	(70,000)		0
Book value	$ 49,025,000		4,683,000
Expansion Capital Facility | Revolving Credit Facility
Long-Term Debt
Face amount			1,120,000,000
LONG-TERM DEBT, debt issuance costs			0
Book value			1,120,000,000
Working Capital Facility | Revolving Credit Facility
Long-Term Debt
Face amount			350,000,000
LONG-TERM DEBT, debt issuance costs			0
Book value			$ 350,000,000

Long Term Debt - 2026 Senior Se

Long Term Debt - 2026 Senior Secured Notes (Details) $ in Thousands	Feb. 04, 2021USD ($)
7.5% Senior Secured Notes due 2026
Long-Term Debt
Face amount	$ 2,050,000
Fixed interest rate	7.50%
Debt instrument, total leverage ratio	4.75
2026 Senior Secured Notes redemption terms	We have an option to redeem all or a portion of the 2026 Senior Secured Notes at any time on or after February 1, 2023 at fixed redemption prices contained within the Indenture. Prior to such time, we, at our option, may redeem up to 40% of the aggregate principal amount of the 2026 Senior Secured Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at the redemption price specified in the Indenture. In addition, before February 1, 2023, we may redeem some or all of the 2026 Senior Secured Notes at a redemption price equal to 100% of the aggregate principal amount of the 2026 Senior Secured Notes redeemed, plus the applicable premium as specified in the Indenture and accrued and unpaid interest, if any, to, but not including, the redemption date. If we experience certain kinds of change of control triggering events, we will be required to offer to repurchase the 2026 Senior Secured Notes at 101% of the aggregate principal amount of the 2026 Senior Secured Notes repurchased plus accrued and unpaid interest on the 2026 Senior Secured Notes repurchased to, but not including, the date of purchase.
2026 Senior Secured Notes and ABL Facility
Long-Term Debt
2026 Senior Secured Notes and ABL Facility offering costs	$ 150,700

Long-Term Debt - Asset Based Cr

Long-Term Debt - Asset Based Credit Facility (Details) - USD ($)	Feb. 04, 2021	Mar. 31, 2021	Mar. 31, 2020
Long-Term Debt
Face amount		$ 3,376,768,000	$ 3,169,326,000
Asset Based Credit Facility
Long-Term Debt
Interest rate		5.25%
Asset Based Credit Facility
Long-Term Debt
Maximum borrowing capacity	$ 500,000,000
Face amount		$ 4,000,000
Secured debt, interest rate description	The ABL Facility is scheduled to mature at the earliest of (a) February 4, 2026 or (b) 91 days prior to the earliest maturity date in respect to any of our indebtedness in an aggregate principal amount of $50.0 million or greater, if such indebtedness is outstanding at such time, subject to certain exceptions. The ABL Facility bears interest at a LIBOR-based rate (with such customary provisions under the ABL Facility providing for the replacement of LIBOR with any successor rate) or an alternate base rate, in each case plus an applicable borrowing margin based on our Fixed Charge Coverage Ratio (as defined in the New Credit Agreement). The applicable margin for alternate base rate loans varies from 1.50% to 2.00% and the applicable margin for LIBOR-based loans varies from 2.50% to 3.00%. In addition, a commitment fee will be charged and payable quarterly in arrears based on the average daily unused portion of the revolving commitments under the ABL Facility. Such commitment fee will be 0.50% per year, subject to a reduction to 0.375% in the event our Fixed Charge Coverage Ratio is greater than or equal to 1.75 to 1.00.
Asset Based Credit Facility | Prime rate
Long-Term Debt
Reference rate		3.25%
Interest rate margin added to variable rate base		2.00%
Asset Based Credit Facility | Letters of credit
Long-Term Debt
Maximum borrowing capacity	$ 200,000,000
Fixed interest rate		3.00%
Letters of credit | Asset Based Credit Facility
Long-Term Debt
Outstanding letters of credit		$ 156,000,000

Long-Term Debt - Senior Unsecur

Long-Term Debt - Senior Unsecured Notes (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	Apr. 09, 2019	Feb. 22, 2017	Oct. 24, 2016	Jul. 09, 2014	Oct. 16, 2013
Long-Term Debt
Notes repurchased	$ 555,562	$ 0	$ 0
Cash paid (excluding payments of accrued interest)	115,796	454	737,058
(Loss) gain on early extinguishment of liabilities, net	(16,692)	1,341	(12,340)
5.125% Senior Notes due 2019
Long-Term Debt
Face amount							$ 400,000
Fixed interest rate							5.125%
5.125% Senior Notes due 2019 | Redemptions
Long-Term Debt
Notes repurchased			328,005
Cash paid (excluding payments of accrued interest)			329,719
(Loss) gain on early extinguishment of liabilities, net			(2,113)
Write off of debt issuance costs			400
5.125% Senior Notes due 2019 | Repurchases
Long-Term Debt
Notes repurchased			25,419
Cash paid (excluding payments of accrued interest)			25,406
(Loss) gain on early extinguishment of liabilities, net			(34)
Write off of debt issuance costs			100
6.875% Senior Notes due 2021
Long-Term Debt
Face amount								$ 450,000
Fixed interest rate								6.875%
6.875% Senior Notes due 2021 | Redemptions
Long-Term Debt
Notes repurchased			367,048
Cash paid (excluding payments of accrued interest)			373,358
(Loss) gain on early extinguishment of liabilities, net			(10,130)
Write off of debt issuance costs			3,800
7.5% Senior Notes due 2023
Long-Term Debt
Face amount						$ 700,000
Fixed interest rate						7.50%
7.5% Senior Notes due 2023 | Repurchases
Long-Term Debt
Notes repurchased	52,072		8,624
Cash paid (excluding payments of accrued interest)	33,566		8,575
(Loss) gain on early extinguishment of liabilities, net	18,096		(63)
Write off of debt issuance costs	400		$ 100
6.125% Senior Notes due 2025
Long-Term Debt
Face amount					$ 500,000
Fixed interest rate					6.125%
6.125% Senior Notes due 2025 | Repurchases
Long-Term Debt
Notes repurchased	7,300	1,815
Cash paid (excluding payments of accrued interest)	3,647	454
(Loss) gain on early extinguishment of liabilities, net	3,575	1,341
Write off of debt issuance costs	100	$ 100
7.5% Senior Notes due 2026
Long-Term Debt
Face amount				$ 450,000
Fixed interest rate				7.50%
7.5% Senior Notes due 2026 | Repurchases
Long-Term Debt
Notes repurchased	111,598
Cash paid (excluding payments of accrued interest)	78,583
(Loss) gain on early extinguishment of liabilities, net	31,463
Write off of debt issuance costs	$ 1,600

Long-Term Debt - Credit Agreeme

Long-Term Debt - Credit Agreement (Details) - Revolving Credit Facility $ in Thousands	Feb. 04, 2021USD ($)
Long-Term Debt
Maximum borrowing capacity	$ 1,915,000
Termination fees for Credit Agreement	300
Working Capital Facility
Long-Term Debt
Maximum borrowing capacity	350,000
Expansion Capital Facility
Long-Term Debt
Maximum borrowing capacity	$ 1,565,000

Long-Term Debt - Term Credit Ag

Long-Term Debt - Term Credit Agreement (Details) - Term Credit Agreement - USD ($) $ in Thousands	Feb. 04, 2021	Jun. 03, 2020
Long-Term Debt
Secured debt		$ 250,000
Term Credit Agreement make-whole fee	$ 55,600
Write off of debt issuance costs	7,400
Termination fees for Credit Agreement	$ 100

Long-Term Debt - Bridge Term Cr

Long-Term Debt - Bridge Term Credit Agreement (Details) - Bridge Term Credit Agreement - USD ($) $ in Millions	Jun. 03, 2020	Jul. 02, 2019
Long-Term Debt
Secured debt		$ 250
Write off of debt issuance costs	$ 2.3

Long-Term Debt - Sawtooth Credi

Long-Term Debt - Sawtooth Credit Agreement (Details) - USD ($)	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Line of Credit Facility
Face amount	$ 3,376,768,000	$ 3,169,326,000
Sawtooth Credit Agreement
Line of Credit Facility
Interest rate	2.36%
Sawtooth Credit Agreement
Line of Credit Facility
Ownership percentage in Sawtooth	71.50%
Maximum borrowing capacity	$ 20,000,000
Face amount	$ 5,000,000
Commitment fees charged on unused capacity	0.50%

Long-Term Debt - Other Long-Ter

Long-Term Debt - Other Long-Term Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Oct. 29, 2020	Mar. 31, 2020
Long-Term Debt
Face amount	$ 3,376,768		$ 3,169,326
Equipment Loan Secured by Certain Barges and Towboats
Long-Term Debt
Face amount	$ 44,100	$ 45,000
Fixed interest rate		8.60%

Long-Term Debt - Debt Maturity

Long-Term Debt - Debt Maturity Schedule (Details) $ in Thousands	Mar. 31, 2021USD ($)
Maturities
2022	$ 2,184
2023	7,585
2024	558,067
2025	383,088
2026	2,057,343
Thereafter	368,501
Total	3,376,768
7.5% Senior Secured Notes due 2026
Maturities
2026	2,050,000
Total	2,050,000
Asset Based Credit Facility
Maturities
2026	4,000
Total	4,000
Senior Unsecured Notes
Maturities
2024	555,251
2025	380,020
2026	0
Thereafter	338,402
Total	1,273,673
Other long-term debt
Maturities
2022	2,184
2023	7,585
2024	2,816
2025	3,068
2026	3,343
Thereafter	30,099
Total	$ 49,095

Long-Term Debt - Amortization o

Long-Term Debt - Amortization of Debt Issuance Costs (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Debt Disclosure [Abstract]
Amortization of debt issuance costs	$ 7,800	$ 5,400	$ 4,300
Expected Future Amortization of Debt Issuance Costs
2022	12,247
2023	12,247
2024	11,677
2025	10,802
2026	8,529
Thereafter	53
Total	$ 55,555

Commitments and Contingencies -

Commitments and Contingencies - Legal Contingencies (Details) $ in Millions	12 Months Ended
	Mar. 31, 2021USD ($)
Loss Contingencies
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) number in Millions, $ in Millions	12 Months Ended
	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)	Mar. 31, 2021USD ($)
Environmental matter
Environmental matters liability			$ 1.7
Litigation settlement, cash portion		$ 25
Litigation settlement, renewable identification numbers		36
Litigation settlement expense	$ 12.5	$ 12.5

Commitments and Contingencies_3

Commitments and Contingencies - Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	$ 18,416	$ 9,723
Liabilities incurred	7,952	1,643
Liabilities assumed in acquisitions		6,642
Liabilities associated with disposed assets (1)	(22)
Liabilities settled		(658)
Accretion expense	1,733	1,066
Balance at end of period	$ 28,079	$ 18,416

Commitments and Contingencies_4

Commitments and Contingencies - Other Commitments (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Future minimum payments
2022	$ 10,074
2023	4,568
2024	4,568
2025	74
2026	55
Thereafter	275
Total	19,614
Hillstone Subsidy Payment
Loss Contingencies
Subsidy payment	2,600	$ 800
Minimum | Hillstone Subsidy Payment
Loss Contingencies
Contractual obligation	0
Maximum | Hillstone Subsidy Payment
Loss Contingencies
Contractual obligation	$ 5,700

Commitments and Contingencies_5

Commitments and Contingencies - Pipeline Capacity Agreements (Details) $ in Thousands	12 Months Ended
	Mar. 31, 2021USD ($)
Customer contracts
Future minimum throughput payments
Number of months to continue shipping after maturity date of contract	6 months
Pipeline capacity agreements
Future minimum throughput payments
2022	$ 35,314
2023	35,314
2024	35,410
2025	30,897
Total	$ 136,935

Commitments and Contingencies_6

Commitments and Contingencies - Purchase Commitments (Details) gal in Thousands, bbl in Thousands, $ in Thousands	Mar. 31, 2021USD ($)bblgal
Crude oil
Purchase commitments for crude oil and natural gas
Fixed-price purchase commitments, due in next twelve months	$ 93,285
Fixed-price purchase commitments (in barrels/gallons), due in next twelve months | bbl	1,515
Total fixed-price purchase commitments	$ 93,285
Total fixed-price purchase commitments (in barrels/gallons) | bbl	1,515
Index-price purchase commitments, due in next twelve months	$ 3,038,806
Index-price purchase commitments (in barrels/gallons), due in next twelve months | bbl	54,413
Index-price purchase commitments, due in second year	$ 1,835,567
Index-price purchase commitments (in barrels/gallons), due in second year | bbl	35,588
Index-price purchase commitments, due in third year	$ 1,715,198
Index-price purchase commitments (in barrels), due in third year | bbl	34,775
Index-price purchase commitments, due in fourth year	$ 1,532,174
Index-price purchase commitments (in barrels), due in fourth year | bbl	31,938
Index-price purchase commitments, due in fifth year	$ 938,787
Index-price purchase commitments (in barrels), due in fifth year | bbl	20,263
Total index-price purchase commitments	$ 9,060,532
Total index-price purchase commitments (in barrels/gallons) | bbl	176,977
Natural gas liquids
Purchase commitments for crude oil and natural gas
Fixed-price purchase commitments, due in next twelve months	$ 12,705
Fixed-price purchase commitments (in barrels/gallons), due in next twelve months | gal	21,936
Fixed-price purchase commitments, due in second year	$ 819
Fixed-price purchase commitments (in gallons), due in second year | gal	1,260
Total fixed-price purchase commitments	$ 13,524
Total fixed-price purchase commitments (in barrels/gallons) | gal	23,196
Index-price purchase commitments, due in next twelve months	$ 848,891
Index-price purchase commitments (in barrels/gallons), due in next twelve months | gal	1,094,967
Index-price purchase commitments, due in second year	$ 2,848
Index-price purchase commitments (in barrels/gallons), due in second year | gal	4,774
Total index-price purchase commitments	$ 851,739
Total index-price purchase commitments (in barrels/gallons) | gal	1,099,741

Commitments and Contingencies_7

Commitments and Contingencies - Sales Commitments (Details) gal in Thousands, bbl in Thousands, $ in Thousands	Mar. 31, 2021USD ($)bblgal	Mar. 31, 2020USD ($)
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 15,704	$ 18,910
Crude oil
Sales commitments for crude oil and natural gas
Fixed-price sale commitments, due in next twelve months	$ 93,464
Fixed-price sales commitments (in barrels/gallons), due in next twelve months | bbl	1,515
Total fixed-price sale commitments	$ 93,464
Total fixed-price sale commitments (in barrels/gallons) | bbl	1,515
Index-price sale commitments, due in next twelve months	$ 3,147,543
Index-price sale commitments (in barrels/gallons), due in next twelve months | bbl	54,634
Unrecorded Unconditional Obligation Outstanding Index Price Sales Contracts, Due in Year two	$ 1,106,564
Index-Price Sale Commitments, Due in Year Two | bbl	20,988
Unrecorded Unconditional Obligation Outstanding Index Price Sales Contracts, Due in Year Three	$ 1,058,526
Index-Price Sale Commitments, Due in Year Three | bbl	21,045
Unrecorded Unconditional Obligation Outstanding Index Price Sales Contracts, Due in Year Four	$ 1,024,037
Index-Price Sale Commitments, Due in Year Four | bbl	20,988
Unrecorded Unconditional Obligation Outstanding Index Price Sales Contracts, Due in Year Five	$ 484,326
Index-Price Sale Commitments, Due in Year Five | bbl	10,242
Total index-price sale commitments	$ 6,820,996
Total index-price sale commitments (in barrels/gallons) | bbl	127,897
Natural gas liquids
Sales commitments for crude oil and natural gas
Fixed-price sale commitments, due in next twelve months	$ 36,731
Fixed-price sales commitments (in barrels/gallons), due in next twelve months | gal	45,827
Fixed-price sale commitments, due in second year	$ 2,568
Fixed-price sale commitments (in gallons), due in second year | gal	3,640
Total fixed-price sale commitments	$ 39,299
Total fixed-price sale commitments (in barrels/gallons) | gal	49,467
Index-price sale commitments, due in next twelve months	$ 546,242
Index-price sale commitments (in barrels/gallons), due in next twelve months | gal	558,346
Index-price sale commitments, due in second year	$ 1,686
Index-price commitments (in gallons), due in second year | gal	2,088
Total index-price sale commitments	$ 547,928
Total index-price sale commitments (in barrels/gallons) | gal	560,434
Prepaid expenses and other current assets
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 37,200
Accrued expenses and other payables
Sales commitments for crude oil and natural gas
Net commodity asset (liability)	$ 24,000

Equity - Partnership Equity and

Equity - Partnership Equity and General Partner Contributions (Details) - USD ($) $ in Millions	12 Months Ended	36 Months Ended
	Mar. 31, 2021	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Equity
General partners' capital account, notional units issued (in units)	823	823	4,268	3,039
General Partner
Equity
Notional units issued		$ 0.1
Common units
Equity
Ownership interest in NGL Energy Holdings LLC	8.69%	8.69%
General Partner
Equity
General partner interest	0.10%
General Partner | Common units
Equity
General partner interest	0.10%
Limited Partner
Equity
Limited partner interest	99.90%

Equity - Common Unit Repurchase

Equity - Common Unit Repurchase Program (Details) $ in Millions	Aug. 30, 2019USD ($)
Share Repurchase Program
Common unit repurchase program, authorized amount	$ 150

Equity - Distributions (Details

Equity - Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Nov. 13, 2020	Oct. 27, 2020	Aug. 14, 2020	Jul. 23, 2020	May 15, 2020	Apr. 27, 2020	Feb. 14, 2020	Jan. 23, 2020	Nov. 14, 2019	Oct. 23, 2019	Aug. 14, 2019	Jul. 23, 2019	May 15, 2019	Apr. 24, 2019	Feb. 14, 2019	Jan. 22, 2019	Nov. 14, 2018	Oct. 23, 2018	Aug. 14, 2018	Jul. 24, 2018	May 15, 2018	Apr. 24, 2018
Equity [Abstract]
Amount Per Unit (in dollars per unit)		$ 0.1000		$ 0.2000		$ 0.2000		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900		$ 0.3900
Amount Paid to Limited Partners	$ 12,877		$ 25,754		$ 25,754		$ 50,056		$ 49,936		$ 49,217		$ 49,127		$ 48,373		$ 48,260		$ 47,600		$ 47,374
Amount Paid to General Partner	$ 13		$ 26		$ 26		$ 86		$ 86		$ 85		$ 85		$ 83		$ 83		$ 82		$ 82

Equity - Class A Convertible Pr

Equity - Class A Convertible Preferred Units (Details) - USD ($)	May 11, 2019	May 10, 2019	Apr. 05, 2019	Feb. 14, 2019	Nov. 14, 2018	Aug. 14, 2018	May 15, 2018	Apr. 26, 2018	Apr. 21, 2016	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	Jun. 30, 2017	Jun. 24, 2016	Jun. 23, 2016
Preferred Units
Accretion of beneficial conversion feature											$ 36,517,000	$ 67,239,000
Repurchase of warrants										$ 0	$ 0	$ 14,988,000
Class A Convertible Preferred Units
Preferred Units
Temporary equity, issued (in units)											19,942,169
Oaktree Capital Management L.P.
Preferred Units
Preferred units, authorized amount									$ 200,000,000						$ 240,000,000
Oaktree Capital Management L.P. | Warrant
Preferred Units
Warrants outstanding (in units)													4,375,112
Class of warrant or right, exercise price														$ 0.01
Warrants exercised and converted to common units (in units)			1,458,371									228,797
Proceeds from warrant exercises			$ 100,000									$ 100,000
Repurchase of warrants (in units)								1,229,575
Repurchase of warrants								$ 15,000,000
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
Accretion of beneficial conversion feature											$ 36,500,000	$ 67,200,000
Preferred units redeemed	12,473,191		7,468,978
Preferrred unit redemption price per unit excluding unpaid dividends	$ 13.2385		$ 13.389
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
Preferred unit redemption price per unit	$ 13.3822		$ 13.727
Preferred unit redemption amount	$ 166,900,000		$ 102,500,000
Amount paid to preferred unitholders		$ 4,034,000		$ 6,449,000	$ 6,449,000	$ 6,449,000	$ 6,449,000
Distributions made to preferred unitholders distributions declared per unit		$ 0.3234

Equity - Class B Preferred Unit

Equity - Class B Preferred Units (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 15, 2021	Oct. 15, 2020	Jul. 15, 2020	Apr. 15, 2020	Jan. 15, 2020	Oct. 15, 2019	Jul. 15, 2019	Jul. 02, 2019	Apr. 15, 2019	Jan. 15, 2019	Oct. 15, 2018	Jul. 16, 2018	Apr. 16, 2018	Jun. 13, 2017	Mar. 31, 2021
Class B Perpetual Preferred Units
Preferred Units
Preferred units dividend rate														9.00%
Preferred unit par or stated value per share														$ 25
Units issued, net of offering costs (Note 10)														$ 202,700
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%.
Distributions made to preferred unitholders distributions declared per unit	$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625		$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625	$ 0.5625		$ 0.5625
Amount paid to preferred unitholders	$ 7,079	$ 7,079	$ 7,079	$ 7,079	$ 7,079	$ 7,079	$ 4,725		$ 4,725	$ 4,725	$ 4,725	$ 4,725	$ 4,725
Class B Perpetual Preferred Units
Preferred Units
Preferred units, dividend payment terms														The current distribution rate for the Class B Preferred Units is 9.00% per year of the $25.00 liquidation preference per unit (equal to $2.25 per unit per year).
Class B Perpetual Preferred Units | Class B Perpetual Preferred Units
Preferred Units
Units issued (in units)														8,400,000
Class B Perpetual Preferred Units | Class B Perpetual Preferred Units
Preferred Units
Units issued (in units)								4,185,642

Equity - Class C Preferred Unit

Equity - Class C Preferred Units (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 15, 2021	Oct. 15, 2020	Jul. 15, 2020	Apr. 15, 2020	Jan. 15, 2020	Oct. 15, 2019	Jul. 15, 2019	Apr. 02, 2019	Mar. 31, 2021
Class C Perpetual Preferred Units
Preferred Units
Preferred units dividend rate								9.625%
Preferred unit par or stated value per share								$ 25
Units issued, net of offering costs (Note 10)								$ 42,900
Preferred units, underwriting discounts and commissions								1,400
Preferred units, offering costs								$ 700
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. 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%.
Distributions made to preferred unitholders distributions declared per unit	$ 0.6016	$ 0.6016	$ 0.6016	$ 0.6016	$ 0.6016	$ 0.6016	$ 0.5949		$ 0.6016
Amount paid to preferred unitholders	$ 1,083	$ 1,083	$ 1,083	$ 1,083	$ 1,083	$ 1,083	$ 1,071
Class C Perpetual Preferred Units
Preferred Units
Preferred units, dividend payment terms								The current distribution rate for the Class C Preferred Units is 9.625% per year of the $25.00 liquidation preference per unit (equal to $2.41 per unit per year).
Class C Perpetual Preferred Units | Class C Perpetual Preferred Units
Preferred Units
Units issued (in units)								1,800,000

Equity - Class D Preferred Unit

Equity - Class D Preferred Units (Details) $ / shares in Units, $ in Thousands	Feb. 12, 2021USD ($)$ / shares	Nov. 13, 2020USD ($)$ / shares	Aug. 14, 2020USD ($)$ / shares	May 15, 2020USD ($)$ / shares	Feb. 14, 2020USD ($)$ / shares	Nov. 14, 2019USD ($)$ / shares	Oct. 31, 2019USD ($)$ / sharesshares	Jul. 02, 2019USD ($)$ / sharesshares	Feb. 12, 2021$ / shares	Oct. 31, 2019USD ($)$ / sharesshares	Mar. 31, 2020USD ($)	Mar. 31, 2021$ / shares
Class of Stock
Issuance of warrants, net of offering costs (Note 10)											$ 52,742
Class D Preferred Units
Class of Stock
Preferred units, dividend payment terms								The holders of the Class D Preferred Units are entitled to receive a cumulative, quarterly distribution in arrears on each Class D Preferred Unit then held at an annual rate of (i) 9.00% per annum for all periods during which the Class D Preferred Units are outstanding beginning on the Closing Date and ending on the date and including the last day of the eleventh full quarter following the Closing Date, (ii) 10.00% per annum for all periods during which the Class D Preferred Units are outstanding beginning on and including the first day of the twelfth full quarter following the Closing Date and ending on the last day of the nineteenth full quarter following the Closing Date, and (iii) thereafter, 10.00% per annum or, at the purchasers’ election from time to time, a floating rate equal to the applicable three-month LIBOR, plus 7.00% per annum. The current distribution rate for the Class D Preferred Units is 9.00% per year per unit (equal to $90.00 per unit per year).
Preferred units, redemption terms										At any time after the Closing Date, the Partnership shall have the right to redeem all of the outstanding Class D Preferred Units at a price per Class D Preferred Unit equal to the sum of the then-unpaid accumulations with respect to such Class D Preferred Unit and the greater of either the applicable multiple on invested capital or the applicable redemption price based on an applicable internal rate of return, as more fully described in the Amended and Restated Partnership Agreement. At any time on or after the eighth anniversary of the Closing Date, each Class D Preferred Unitholder will have the right to require the Partnership to redeem on a date not prior to the 180th day after such anniversary all or a portion of the Class D Preferred Units then held by such preferred unitholder for the then-applicable redemption price, which may be paid in cash or, at the Partnership’s election, a combination of cash and a number of common units not to exceed one-half of the aggregate then-applicable redemption price, as more fully described in the Amended and Restated Partnership Agreement. Upon a Class D Change of Control (as defined in the Amended and Restated Partnership Agreement), each Class D Preferred Unitholder will have the right to require the Partnership to redeem the Class D Preferred Units then held by such Preferred Unitholder at a price per Class D Preferred Unit equal to the applicable redemption price. The Class D Preferred Units generally will not have any voting rights, except with respect to certain matters which require the vote of the Class D Preferred Units. The Class D Preferred Units generally do not have any voting rights, except that the Class D Preferred Units shall be entitled to vote as a separate class on any matter on which unitholders are entitled to vote that adversely affects the rights, powers, privileges or preferences of the Class D Preferred Units in relation to other classes of Partnership Interests (as defined in the Amended and Restated Partnership Agreement) or as required by law. The consent of a majority of the then-outstanding Class D Preferred Units, with one vote per Class D Preferred Unit, shall be required to approve any matter for which the preferred unitholders are entitled to vote as a separate class or the consent of the representative of the Class D Preferred Unitholders, as applicable.
Preferred units, change of control terms										Upon a change of control, all unvested warrants shall immediately vest and be exercisable in full. A change of control occurs when (a) the current general partner owners cease to own, directly or indirectly, at least 50% of the outstanding voting securities of the general partner, (b) the general partner withdraws or is removed by the limited partners, (c) the common units are no longer listed on a national exchange, or (d) the general partners and/or its affiliates become beneficial owner, directly or indirectly, of 80% or more of the outstanding common units or any transaction or event that occurs due to default on our credit agreement.
Board rights agreement								In connection with the issuance of the Class D Preferred Units, we entered into a board rights agreement pursuant to which affiliates of the purchasers of the Class D Preferred Units (“Purchasers”) will have the right to designate one director on the board of directors of our general partner, so long as the Purchasers and their respective affiliates, in the aggregate, own either at least (i) (A) 50% of the number of Class D Preferred Units issued on the Closing Date or (B) 50% of the aggregate liquidation preference of any class or series of Class D Parity Securities (as defined in the Amended and Restated Partnership Agreement), or (ii) warrants and/or common units that, in the aggregate, comprise 10% or more of the then-outstanding common units.
Class D Preferred Units First Issuance
Class of Stock
Temporary equity, issued (in units) | shares								400,000
Preferred units, authorized amount								$ 400,000
Proceeds from sale of preferred units and warrants, net of offering costs								385,400
Closing fee payable to affiliates of the purchaser								14,600
Allocation of net proceeds to Class D Preferred Units								$ 343,700
Class D Preferred Units Second Issuance
Class of Stock
Temporary equity, issued (in units) | shares							200,000			200,000
Preferred units, authorized amount							$ 200,000			$ 200,000
Proceeds from sale of preferred units and warrants, net of offering costs							194,700
Closing fee payable to affiliates of the purchaser							5,300			$ 5,300
Allocation of net proceeds to Class D Preferred Units							$ 183,600
Class D Preferred Units
Class of Stock
Distributions made to preferred unitholders distributions declared per unit | $ / shares	$ 26.01	$ 26.01	$ 11.25	$ 11.25	$ 11.25	$ 11.25			$ 26.01			$ 26.01
Amount paid to preferred unitholders	$ 15,608	$ 15,608	$ 6,946	$ 6,868	$ 6,075	$ 4,450
Adjusted Total Leverage Ratio Default Rate									0.010
Dividends paid-in-kind			$ 6,900								$ 17,400
Percent of dividend not paid in cash			50.00%								50.00%
Class D Preferred Units First Issuance
Class of Stock
Warrants outstanding (in units) | shares								17,000,000
Class D Preferred Units Second Issuance
Class of Stock
Warrants outstanding (in units) | shares							8,500,000			8,500,000
Warrant | Class D Preferred Units First Issuance
Class of Stock
Issuance of warrants, net of offering costs (Note 10)								$ 41,700
Warrant | Class D Preferred Units Second Issuance
Class of Stock
Issuance of warrants, net of offering costs (Note 10)							$ 11,100
Premium Warrants | Class D Preferred Units First Issuance
Class of Stock
Warrants outstanding (in units) | shares								10,000,000
Class of warrant or right, exercise price | $ / shares								$ 17.45
Premium Warrants | Class D Preferred Units Second Issuance
Class of Stock
Warrants outstanding (in units) | shares							5,000,000			5,000,000
Class of warrant or right, exercise price | $ / shares							$ 16.28			$ 16.28
Par Warrants | Class D Preferred Units First Issuance
Class of Stock
Warrants outstanding (in units) | shares								7,000,000
Class of warrant or right, exercise price | $ / shares								$ 14.54
Par Warrants | Class D Preferred Units Second Issuance
Class of Stock
Warrants outstanding (in units) | shares							3,500,000			3,500,000
Class of warrant or right, exercise price | $ / shares							$ 13.56			$ 13.56

Equity - Equity-Based Incentive

Equity - Equity-Based Incentive Compensation - Service Awards (Details) - USD ($)	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2018
Cancellation of Common Units for Tax Withholding
Common units canceled during period (in units)	70,226
Value of common units canceled during period	$ 200,000
Deferred Compensation Arrangements
Accrued bonuses			$ 8,700,000	$ 6,300,000
Service awards
Equity-Based Incentive Compensation
Weighted-average grant price	$ 3.76	$ 12.84	$ 9.74
Expense recorded	$ 4,700,000	$ 8,500,000	$ 12,000,000
Service Award Activity
Unvested restricted units at the beginning of the period (in units)	1,371,425	2,308,400	2,278,875
Units granted (in units)	7,000	2,211,431	3,141,993
Units vested and issued (in units)	(892,450)	(2,938,481)	(2,833,968)
Units forfeited (in units)	(39,000)	(209,925)	(278,500)
Unvested restricted units at the end of the period (in units)	446,975	1,371,425	2,308,400
Deferred Compensation Arrangements
Deferred compensation arrangement with individual, fair value of units issued		$ 24,500,000	$ 22,800,000
Expected Future Expense
Estimated expense in next twelve months	$ 1,700,000
Restricted units
Equity-Based Incentive Compensation
Distributions on Service Awards during the vesting period	$ 0
2022 | Service awards
Expected Future Expense
Unvested Service Awards	446,975
Deferred Compensation, Share-based Payments | Deferred Bonus
Deferred Compensation Arrangements
Deferred compensation units granted (in units)	0	1,886,131	1,922,618

Equity - Equity-Based Incenti_2

Equity - Equity-Based Incentive Compensation - Performance Awards (Details) - Performance awards $ in Millions	12 Months Ended
	Mar. 31, 2019USD ($)shares
Performance Award Activity
Unvested restricted units at the beginning of the period (in units)	917,000
Units forfeited (in units)	(445,500)
Units canceled (in units)	(471,500)
Unvested restricted units at the end of the period (in units)	0
Expense recorded | $	$ 4.9
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	May 10, 2021	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	May 11, 2021
Restricted units
LTIP
Number of units available for grant		3,300,000
Restricted units | Subsequent Event
LTIP
Number of units available for grant					0
Deferred Bonus | Deferred Compensation, Share-based Payments
LTIP
Deferred compensation units granted (in units)		0	1,886,131	1,922,618
Service awards
LTIP
Units granted (in units)		7,000	2,211,431	3,141,993
Service awards | Subsequent Event
LTIP
Units granted (in units)	3,300,000

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, 2021	Mar. 31, 2020
Derivative assets (liabilities)
Net commodity derivative asset	$ 15,704	$ 18,910
Prepaid expenses and other current assets
Derivative assets (liabilities)
Net commodity derivative asset	37,200
Accrued expenses and other payables
Derivative assets (liabilities)
Net commodity derivative asset	24,000
Commodity contracts
Assets:
Derivative assets	49,832	89,254
Netting of counterparty contracts, assets	(12,648)	(2,282)
Net cash collateral provided (held)	2,660	(50,104)
Commodity derivatives	39,844	36,868
Liabilities:
Derivative liabilities	(42,331)	(19,870)
Netting of counterparty contracts, liabilities	12,648	2,282
Net cash collateral provided (held)	5,543	(370)
Commodity derivatives	(24,140)	(17,958)
Derivative assets (liabilities)
Net commodity derivative asset	15,704	18,910
Commodity contracts | Prepaid expenses and other current assets
Derivative assets (liabilities)
Net commodity derivative asset	39,844	36,868
Commodity contracts | Accrued expenses and other payables
Derivative assets (liabilities)
Net commodity derivative asset	(21,562)	(17,777)
Commodity contracts | Other noncurrent liabilities
Derivative assets (liabilities)
Net commodity derivative asset	(2,578)	(181)
Level 1 | Commodity contracts
Assets:
Derivative assets	12,312	64,037
Liabilities:
Derivative liabilities	(17,857)	(2,235)
Level 2 | Commodity contracts
Assets:
Derivative assets	37,520	25,217
Liabilities:
Derivative liabilities	$ (24,474)	$ (17,635)

Fair Value of Financial Instr_4

Fair Value of Financial Instruments - Derivative Contract Positions (Details) bbl in Thousands, $ in Thousands	Mar. 31, 2021USD ($)bbl	Mar. 31, 2020USD ($)bbl
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 7,501	$ 69,384
Net cash collateral provided (held)	8,203	(50,474)
Net commodity derivative (liability) asset	15,704	18,910
Crude oil fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (5,414)	$ 41,721
Crude oil fixed-price | Short
Derivative contract information
Derivative, Nonmonetary Notional Amount | bbl	(1,850)	(2,252)
Propane fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 2,188	$ (738)
Propane fixed-price | Long
Derivative contract information
Derivative, Nonmonetary Notional Amount | bbl		415
Propane fixed-price | Short
Derivative contract information
Derivative, Nonmonetary Notional Amount | bbl	(195)
Refined products fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 1,928	$ 27,401
Refined products fixed-price | Short
Derivative contract information
Derivative, Nonmonetary Notional Amount | bbl	(503)	(26)
Butane fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (3,764)
Butane fixed-price | Short
Derivative contract information
Derivative, Nonmonetary Notional Amount | bbl	(753)
Other
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 12,563	$ 1,000

Fair Value of Financial Instr_5

Fair Value of Financial Instruments - (Losses) Gains From Commodity Derivatives (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Net adjustments to fair value of commodity derivatives	$ (83,578)	$ 85,941	$ 10,817

Fair Value of Financial Instr_6

Fair Value of Financial Instruments - Interest Rate Risk (Details) - USD ($)	Mar. 31, 2021	Mar. 31, 2020
Interest Rate Risk
Face amount	$ 3,376,768,000	$ 3,169,326,000
Sawtooth Credit Agreement
Interest Rate Risk
Interest rate	2.36%
Asset Based Credit Facility
Interest Rate Risk
Interest rate	5.25%
Asset Based Credit Facility
Interest Rate Risk
Face amount	$ 4,000,000
Sawtooth Credit Agreement
Interest Rate Risk
Face amount	$ 5,000,000

Fair Value of Financial Instr_7

Fair Value of Financial Instruments - Fair Value of Fixed-Rate Notes (Details) $ in Thousands	Mar. 31, 2021USD ($)
7.5% Senior Secured Notes due 2026
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 2,114,917
7.5% Senior Notes due 2023
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	535,817
6.125% Senior Notes due 2025
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	322,384
7.5% Senior Notes due 2026
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 287,924

Segments (Details)

Segments (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Segment information
Revenues	$ 5,227,023	$ 7,584,000	$ 8,689,157
Depreciation and amortization, including amortization of debt issuance costs	331,200	276,848	221,674
Operating (Loss) Income	(390,753)	(3,332)	126,728
Additions to property, plant and equipment and intangible assets	119,707	2,133,415	670,212
Long-lived assets, net	4,866,051	5,638,330
Total assets	5,947,341	6,498,736
Operating segment | Water solutions
Segment information
Revenues	370,986	422,059	301,686
Depreciation and amortization, including amortization of debt issuance costs	222,354	163,874	108,162
Operating (Loss) Income	(92,720)	(173,064)	210,525
Additions to property, plant and equipment and intangible assets	66,649	2,076,866	567,637
Long-lived assets, net	3,104,450	3,382,727
Total assets	3,204,850	3,539,328
Operating segment | Water solutions | Disposal service fees
Segment information
Revenues	317,640	330,877	217,545
Operating segment | Water solutions | Sale of recovered crude oil
Segment information
Revenues	28,599	59,445	72,678
Operating segment | Water solutions | Sale of brackish non-potable water
Segment information
Revenues	10,554	11,676	2,404
Operating segment | Water solutions | Other revenues
Segment information
Revenues	14,193	20,061	9,017
Operating segment | Water solutions | Non-Topic 606 revenues
Segment information
Non-Topic 606 revenues	0	0	42
Operating segment | Crude oil logistics
Segment information
Revenues	1,721,636	2,549,767	3,136,635
Depreciation and amortization, including amortization of debt issuance costs	60,874	70,759	74,245
Operating (Loss) Income	(304,330)	117,768	(7,379)
Additions to property, plant and equipment and intangible assets	9,933	28,828	28,039
Long-lived assets, net	1,090,578	1,567,503
Total assets	1,665,005	1,886,211
Operating segment | Crude oil logistics | Non-Topic 606 revenues
Segment information
Non-Topic 606 revenues	11,355	13,991	12,598
Operating segment | Crude oil logistics | Crude oil sales
Segment information
Revenues	1,574,699	2,383,812	3,011,355
Operating segment | Crude oil logistics | Crude oil transportation and other
Segment information
Revenues	142,233	170,138	148,738
Operating segment | Liquids Logistics
Segment information
Revenues	3,133,146	4,611,136	5,249,474
Depreciation and amortization, including amortization of debt issuance costs	29,503	28,279	27,034
Operating (Loss) Income	70,441	142,411	9,288
Additions to property, plant and equipment and intangible assets	31,172	19,753	72,717
Long-lived assets, net	626,221	654,530
Total assets	1,003,370	972,684
Operating segment | Liquids Logistics | Other revenues
Segment information
Revenues	22,270	37,938	26,655
Operating segment | Liquids Logistics | Non-Topic 606 revenues
Segment information
Non-Topic 606 revenues	79,442	289,713	320,798
Operating segment | Liquids Logistics | Refined products sales
Segment information
Revenues	1,123,963	2,399,642	2,535,243
Operating segment | Liquids Logistics | Propane sales
Segment information
Revenues	1,023,479	842,400	1,169,117
Operating segment | Liquids Logistics | Butane sales
Segment information
Revenues	516,358	562,053	628,063
Operating segment | Liquids Logistics | Other product sales
Segment information
Revenues	373,707	484,373	592,889
Operating segment | Corporate and Other
Segment information
Revenues	1,255	1,038	1,362
Operating segment | Corporate and Other | Non-Topic 606 revenues
Segment information
Non-Topic 606 revenues	1,255	1,038	1,362
Elimination of intersegment sales | Crude oil logistics
Segment information
Revenues	(6,651)	(18,174)	(36,056)
Elimination of intersegment sales | Liquids Logistics
Segment information
Revenues	(6,073)	(4,983)	(23,291)
Corporate and other
Segment information
Depreciation and amortization, including amortization of debt issuance costs	18,469	13,936	12,233
Operating (Loss) Income	(64,144)	(90,447)	(85,706)
Additions to property, plant and equipment and intangible assets	11,953	7,968	$ 1,819
Long-lived assets, net	44,802	33,570
Total assets	74,116	100,513
Non-US | Liquids Logistics
Segment information
Long-lived assets, net	20,900	25,900
Total assets	$ 37,900	$ 37,800

Transactions with Affiliates -

Transactions with Affiliates - Related Party Transactions (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Transactions with Affiliates
Accounts receivable-affiliates	$ 9,435	$ 12,934
Accounts payable-affiliates	119	17,717
WPX Energy
Transactions with Affiliates
Sales to related party	39,129	48,222	$ 28,026
Purchases from related party	216,487	313,578	329,525
Accounts receivable-affiliates	0	3,563
Accounts payable-affiliates	0	17,039
SemGroup
Transactions with Affiliates
Sales to related party		458	1,114
Purchases from related party		0	4,395
Entities affiliated with management
Transactions with Affiliates
Sales to related party	18,402	8,367	21,385
Purchases from related party	1,239	3,799	4,382
Accounts receivable-affiliates	728	151
Accounts payable-affiliates	12	149
Equity method investees
Transactions with Affiliates
Sales to related party	0	203	0
Purchases from related party	3,249	2,120	$ 0
Accounts receivable-affiliates	462	1,439
Accounts payable-affiliates	107	529
NGL Energy Holdings LLC
Transactions with Affiliates
Accounts receivable-affiliates	$ 8,245	$ 7,781

Transactions with Affiliates _2

Transactions with Affiliates - Other Related Party Transactions (Details) $ in Thousands	Feb. 04, 2021USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2021USD ($)	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)	Jun. 30, 2019USD ($)	Aug. 14, 2018USD ($)
Transactions with Affiliates
Ownership interest			50.00%
Number of transactions					3
Investment in NGL Energy Holdings LLC				$ 0	$ (15,226)	$ 0
Promissory note from Victory Propane								$ 3,400
Present value of note receivable from Victory Propane								2,600
Crude oil logistics
Transactions with Affiliates
Write-off of pipeline deficiency credits			$ 67,700
Remaining deficiency payments			50,300
Loss on contract			$ 35,300
NGL Energy Holdings LLC
Transactions with Affiliates
Ownership interest in NGL Energy Holdings LLC		5.73%			2.97%
Equity method investees | Loan agreement
Transactions with Affiliates
Loan receivable from Victory Propane								$ 2,600
NGL Energy Holdings LLC
Transactions with Affiliates
Investment in NGL Energy Holdings LLC		$ (11,500)			$ (3,800)
Operating segment | KAIR2014 LLC | Aircraft Company | Corporate and Other
Transactions with Affiliates
Ownership interest				50.00%
Equity method investment, original cost							$ 900
7.5% Senior Secured Notes due 2026
Transactions with Affiliates
2026 Senior Secured Notes consent cost	$ 40,000

Employee Benefit Plan (Details)

Employee Benefit Plan (Details) - USD ($) $ in Millions	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
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 vest over two years. Effective January 1, 2020, for every dollar that employees contribute up to 4% of their eligible compensation (as defined in the plan), we contribute one dollar, plus 50 cents for every dollar employees contribute between 4% and 6% of their eligible compensation (as defined in the plan).
Defined contribution plan expense	$ 3.4	$ 2.3	$ 1.9

Revenue from Contracts with C_4

Revenue from Contracts with Customers - Revenue Agreements (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Net adjustments to fair value of commodity derivatives	$ (83,578)	$ 85,941	$ 10,817
Liquids Logistics
Net adjustments to fair value of commodity derivatives	$ 11,000

Revenue from Contracts with C_5

Revenue from Contracts with Customers - Performance Obligations (Details) $ in Thousands	Mar. 31, 2021USD ($)
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 371,596
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 111,966
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 101,702
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 78,241
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 56,288
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 17,732
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-04-01
Revenue from Contracts with Customers - Performance Obligations [Abstract]
Revenue expected to be recognized as of March 31, 2021	$ 5,667
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year

Revenue from Contracts with C_6

Revenue from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Contract with Customer, Asset and Liability [Abstract]
Accounts receivable from contracts with customers	$ 436,682	$ 372,930
Contract liabilities balance	11,163	$ 19,536
Payment received and deferred	36,861
Payment recognized in revenue	$ (45,234)

Leases - Lessee Impact of Adopt

Leases - Lessee Impact of Adoption (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Mar. 31, 2020	Apr. 01, 2019
Leases [Abstract]
Operating lease right-of-use asset	$ 152,146	$ 180,708	$ 551,200
Operating lease obligations	$ 150,707		$ 549,000

Leases - Lessee Balance Sheet a

Leases - Lessee Balance Sheet and Income Statement Information (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Mar. 31, 2020	Apr. 01, 2019
Lessee Description
OPERATING LEASE RIGHT-OF-USE ASSETS	$ 152,146	$ 180,708	$ 551,200
Operating lease obligations	47,070	56,776
OPERATING LEASE OBLIGATIONS	103,637	121,013
Operating lease right-of-use asset	152,146	180,708	$ 551,200
Operating lease obligation-current	47,070	56,776
Operating lease obligation-noncurrent	$ 103,637	$ 121,013
Weighted-average remaining lease term	6 years 10 months 17 days	6 years 8 months 26 days
Weighted-average discount rate	7.06%	6.06%
Minimum
Lessee Description
Lessee, operating lease renewal term	1 year
Maximum
Lessee Description
Lessee, operating lease renewal term	30 years

Leases - Lease Expense (Details

Leases - Lease Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Lease, Cost [Abstract]
Operating lease expense	$ 69,031	$ 72,340
Variable lease expense	18,871	19,158
Short-term lease expense	1,217	799
Total lease expense	$ 89,119	$ 92,297
Rental expense			$ 91,600

Leases - Lessee Maturities of O

Leases - Lessee Maturities of Operating Lease Obligations (Details) - USD ($) $ in Thousands	Mar. 31, 2021	Apr. 01, 2019
Leases [Abstract]
2022	$ 53,842
2023	41,395
2024	26,589
2025	15,349
2026	7,406
Thereafter	50,804
Total lease payments	195,385
Less imputed interest	(44,678)
Total operating lease obligations	$ 150,707	$ 549,000

Leases - Lessee Supplemental Ca

Leases - Lessee Supplemental Cash Flow and Non-Cash Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Leases [Abstract]
Cash paid for amounts included in the measurement of operating lease obligations	$ 68,141	$ 101,678
Operating lease right-of-use assets obtained in exchange for operating lease obligations	$ 33,579	$ 598,734

Leases - Lessor Income Statemen

Leases - Lessor Income Statement Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Lessor Description
Operating lease revenues	$ 15,900	$ 20,400
Sublease revenue	$ 2,500	$ 4,600
Minimum
Lessor Description
Lessor, operating lease renewal term	1 year
Maximum
Lessor Description
Lessor, operating lease renewal term	5 years

Leases - Lessor Future Minimum

Leases - Lessor Future Minimum Lease Payments Receivable (Details) $ in Thousands	Mar. 31, 2021USD ($)
Leases [Abstract]
2022	$ 11,944
2023	8,959
2024	4,817
2025	690
2026	416
Thereafter	800
Total	$ 27,626

Allowance for Current Expecte_4

Allowance for Current Expected Credit Loss (Details) - USD ($) $ in Thousands	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2018
Allowance for Expected Credit Loss
Provision for expected credit losses	$ 5,988	$ 1,002	$ 381
Crude oil logistics
Allowance for Expected Credit Loss
Amount owed for deficiency volumes	5,700
Trade Accounts Receivable
Allowance for Expected Credit Loss
Accounts receivable - trade, allowance for expected credit loss	2,192	4,540	4,016	$ 3,851
Cumulative effect adjustment	433	0	0
Provision for expected credit losses	319	1,202	381
Write-offs charged against the allowance	(3,100)	(678)	$ (216)
Notes Receivable and Other
Allowance for Expected Credit Loss
Cumulative effect adjustment	680
Write-offs charged against the allowance	(222)
Notes receivable and other, allowance for expected credit loss	$ 458	$ 0

Other Matters - Third-party Loa

Other Matters - Third-party Loan Receivable (Details) - Third-party Loan Receivable - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2020	Mar. 31, 2021	Mar. 31, 2020
Accounts receivable
Financing receivable, before allowance for credit loss, total	$ 10.4		$ 26.7
Proceeds from collection of receivables	16.3
Write-off of loan receivable	$ 9.4
Financing receivable, after allowance for credit loss		$ 0.6

Other Matters - Third-party Ban

Other Matters - Third-party Bankruptcy (Details) - USD ($)	12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 21, 2020
Accounts receivable
Goodwill impairment	$ 237,800,000	$ 250,000,000
Crude oil logistics
Accounts receivable
Increase in rate based on NYMEX prices			$ 50
Liquidated payment			$ 35,000,000
Carrying value of intangible assets	180,800,000
Goodwill impairment	237,800,000
Amount owed for deficiency volumes	5,700,000
Crude oil logistics | Customer commitments
Accounts receivable
Intangible asset impairment	$ 145,800,000

Other Matters - Sale of Certain

Other Matters - Sale of Certain Assets (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2021
Receivables [Abstract]
Proceeds from sale of assets		$ 43,200
Gain on sale of certain assets			$ 14,000
Holdback of certain proceeds	$ 300

Other Matters - Sale of South P

Other Matters - Sale of South Pecos Water Disposal Business (Details)	Feb. 28, 2019USD ($)	Mar. 31, 2021USD ($)	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net		$ 0	$ 0	$ 335,809,000
Gain on disposal or impairment of assets, net		(475,436,000)	$ (261,786,000)	$ (34,296,000)
Gain on sale of certain assets		$ 14,000,000
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 on disposal or impairment of assets, net	$ 107,900,000
Number of saltwater wells sold	9
Number of permits acquired			2
Proceeds received from sale of permits			$ 15,000,000
Gain on sale of certain assets			$ 14,500,000

Other Matters - Sale of Bakken

Other Matters - Sale of Bakken Saltwater Disposal Business (Details) - USD ($)	Nov. 30, 2018	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net		$ 0	$ 0	$ 335,809,000
Gain on disposal or impairment of assets, net		$ (475,436,000)	$ (261,786,000)	$ (34,296,000)
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 on disposal or impairment of assets, net	$ 33,400,000
Number of saltwater wells sold	5

Other Matters - Sale of E Energ

Other Matters - Sale of E Energy Adams, LLC (Details) - USD ($) $ in Millions	May 03, 2018	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Ownership interest			50.00%
Liquids Logistics | Ethanol Production Facility | Operating segment
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Ownership interest				20.00%
Proceeds from sale of interest in equity method investee	$ 18.6
Gain on sale of interest in equity method investee		$ 3

Other Matters - Sawtooth Joint

Other Matters - Sawtooth Joint Venture (Details) - Sawtooth - USD ($) $ in Millions	36 Months Ended
	Mar. 31, 2021	Mar. 30, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Additional proceeds to acquire remaining interest	$ 182.4
Sawtooth
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Noncontrolling interest, ownership interest percentage		28.50%
Parent, ownership interest percentage		71.50%

Discontinued Operations (Detail

Discontinued Operations (Details) $ in Thousands, gal in Millions	Sep. 30, 2019USD ($)	Jul. 10, 2018USD ($)	Mar. 31, 2021USD ($)gal	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net			$ 0	$ 0	$ 335,809
Loss (gain) on disposal or impairment of assets, net (1)			1,174	203,990	(407,608)
Discontinued operations income attributable to redeemable noncontrolling interests			0	0	(446)
Amount received from DCC and Superior for propane sales			52,300
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Revenues			16,198	12,186,862	15,398,608
Cost of sales			16,556	12,193,307	15,338,614
Operating expenses			290	6,997	37,348
General and administrative expense			0	56	2,716
Depreciation and amortization			0	749	9,593
Loss (gain) on disposal or impairment of assets, net (1)			1,174	203,990	(407,608)
Operating (loss) income from discontinued operations			(1,822)	(218,237)	417,945
Equity in earnings of unconsolidated entities			0	0	1,183
Interest expense			0	(111)	(126)
Other income, net			0	133	837
(Loss) income from discontinued operations before taxes (2)			(1,822)	(218,215)	419,839
Income tax benefit (expense)			53	(20)	(989)
(Loss) Income From Discontinued Operations, net of Tax			$ (1,769)	(218,235)	418,850
Propane sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Sale commitments (in gallons) | gal			3.2
Sale commitments (in dollars)			$ 3,800
Gas Blending
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Loss (gain) on disposal or impairment of assets, net (1)			(1,000)	(14,500)
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Loss (gain) on disposal or impairment of assets, net (1)			(1,000)	(14,500)
TPSL
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Loss (gain) on disposal or impairment of assets, net (1)			200	182,100
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Loss (gain) on disposal or impairment of assets, net (1)			$ 200	182,100
TPSL | Liquids Logistics
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Proceeds from divestitures of businesses and investments, net	$ 233,800
Mid-Con
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Loss (gain) on disposal or impairment of assets, net (1)				(6,300)
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Loss (gain) on disposal or impairment of assets, net (1)				(6,300)
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
Loss (gain) on disposal or impairment of assets, net (1)				1,000	(408,900)
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Loss (gain) on disposal or impairment of assets, net (1)				$ 1,000	(408,900)
Retail Propane Segment - West
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations
Loss (gain) on disposal or impairment of assets, net (1)					1,300
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Loss (gain) on disposal or impairment of assets, net (1)					$ 1,300