NGL Energy Partners (NGL) 10-Q 7 Nov 16 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Sep. 30, 2016	Oct. 31, 2016
Document and Entity Information
Entity Registrant Name	NGL Energy Partners LP
Entity Central Index Key	1,504,461
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Current Fiscal Year End Date	--03-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		107,444,272
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2016	Mar. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents	$ 23,427	$ 28,176
Accounts receivable-trade, net of allowance for doubtful accounts of $5,850 and $6,928, respectively	592,074	521,014
Accounts receivable-affiliates	3,540	15,625
Inventories	520,340	367,806
Prepaid expenses and other current assets	110,918	95,859
Total current assets	1,250,299	1,028,480
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $324,364 and $266,491, respectively	1,755,416	1,649,572
GOODWILL	1,467,955	1,315,362
INTANGIBLE ASSETS, net of accumulated amortization of $356,314 and $316,878, respectively	1,190,147	1,148,890
INVESTMENTS IN UNCONSOLIDATED ENTITIES	190,662	219,550
LOAN RECEIVABLE-AFFILIATE	1,700	22,262
OTHER NONCURRENT ASSETS	217,739	176,039
Total assets	6,073,918	5,560,155
CURRENT LIABILITIES:
Accounts payable-trade	512,104	420,306
Accounts payable-affiliates	6,244	7,193
Accrued expenses and other payables	184,634	214,426
Advance payments received from customers	87,825	56,185
Current maturities of long-term debt	8,046	7,907
Total current liabilities	798,853	706,017
LONG-TERM DEBT, net of debt issuance costs of $13,482 and $15,500, respectively, and current maturities	3,063,008	2,912,837
OTHER NONCURRENT LIABILITIES	198,001	247,236
COMMITMENTS AND CONTINGENCIES (NOTE 10)
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS, 19,942,169 and 0 preferred units issued and outstanding, respectively	58,742	0
EQUITY:
General partner, representing a 0.1% interest, 107,360 and 104,274 notional units, respectively	(50,735)	(50,811)
Limited partners, representing a 99.9% interest, 107,252,272 and 104,169,573 common units issued and outstanding, respectively	1,977,596	1,707,326
Accumulated other comprehensive loss	(642)	(157)
Noncontrolling interests	29,095	37,707
Total equity	1,955,314	1,694,065
Total liabilities, convertible preferred units and equity	$ 6,073,918	$ 5,560,155

Unaudited Condensed Consolidat3

Unaudited Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Mar. 31, 2016	Sep. 30, 2016
Accounts receivable - trade, allowance for doubtful accounts	$ 6,928	$ 5,850
PROPERTY, PLANT AND EQUIPMENT, accumulated depreciation	266,491	324,364
INTANGIBLE ASSETS, accumulated amortization	316,878	356,314
LONG-TERM DEBT, debt issuance costs	$ 15,500	$ 13,482
General partner interest	0.10%	0.10%
General partner, notional units outstanding (in units)	104,274	107,360
Limited partners interest	99.90%	99.90%
Limited partners, common units issued (in units)	104,169,573	107,252,272
Limited partners, common units outstanding (in units)	104,169,573	107,252,272
Class A Convertible Preferred Units
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS, units issued (in units)	0	19,942,169
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS, units outstanding (in units)	0	19,942,169

Unaudited Condensed Consolidat4

Unaudited Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
REVENUES:
Crude Oil Logistics	$ 349,885	$ 1,007,578	$ 775,836	$ 2,335,362
Water Solutions	39,733	47,494	75,486	101,787
Liquids	234,260	258,992	439,309	507,977
Retail Propane	51,090	53,206	111,477	117,653
Refined Products and Renewables	2,370,322	1,825,925	4,364,885	3,668,885
Other	248	0	515	0
Total Revenues	3,045,538	3,193,195	5,767,508	6,731,664
COST OF SALES:
Crude Oil Logistics	340,518	982,719	745,748	2,274,711
Water Solutions	(1,807)	(8,567)	3,394	(4,960)
Liquids	209,283	221,115	400,275	453,391
Retail Propane	20,691	20,879	45,511	50,443
Refined Products and Renewables	2,359,932	1,789,680	4,300,019	3,554,792
Other	113	0	223	0
Total Cost of Sales	2,928,730	3,005,826	5,495,170	6,328,377
OPERATING COSTS AND EXPENSES:
Operating	73,255	97,630	148,427	203,220
General and administrative	27,926	29,298	69,797	91,779
Depreciation and amortization	50,603	56,761	99,509	116,592
Loss (gain) on disposal or impairment of assets, net	852	1,291	(203,467)	1,712
Revaluation of liabilities	0	(15,909)	0	(27,104)
Operating (Loss) Income	(35,828)	18,298	158,072	17,088
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities	53	2,432	447	11,150
Revaluation of investments	0	0	(14,365)	0
Interest expense	(33,442)	(31,571)	(63,880)	(62,373)
Gain on early extinguishment of liabilities	938	0	30,890	0
Other income, net	2,081	1,955	5,853	780
(Loss) Income Before Income Taxes	(66,198)	(8,886)	117,017	(33,355)
INCOME TAX (EXPENSE) BENEFIT	(460)	2,786	(922)	2,248
Net (Loss) Income	(66,658)	(6,100)	116,095	(31,107)
LESS: NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS	59	(3,497)	(5,774)	(7,847)
NET (LOSS) INCOME ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	(66,599)	(9,597)	110,321	(38,954)
LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS	(8,668)	0	(12,052)	0
LESS: NET LOSS (INCOME) ALLOCATED TO GENERAL PARTNER	45	(16,185)	(158)	(31,559)
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	$ (75,222)	$ (25,782)	$ 98,111	$ (70,513)
BASIC (LOSS) INCOME PER COMMON UNIT (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.93	$ (0.67)
DILUTED INCOME LOSS PER COMMON UNIT (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.91	$ (0.67)
BASIC WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	106,186,389	105,189,463	105,183,556	104,542,427
DILUTED WEIGHTED AVERAGE COMMON UNITS OUTSTANDING (in units)	106,186,389	105,189,463	107,997,549	104,542,427

Unaudited Condensed Consolidat5

Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Statement of Comprehensive Income [Abstract]
Net (loss) income	$ (66,658)	$ (6,100)	$ 116,095	$ (31,107)
Other comprehensive loss	(333)	(19)	(485)	(27)
Comprehensive (loss) income	$ (66,991)	$ (6,119)	$ 115,610	$ (31,134)

Unaudited Condensed Consolidat6

Unaudited Condensed Consolidated Statement of Changes in Equity - USD ($) $ in Thousands	Total	Class A Convertible Preferred Units	Accumulated Other Comprehensive Loss	Noncontrolling Interests	General Partner	Limited Partner	Limited PartnerClass A Convertible Preferred Units	Limited PartnerCommon units
Beginning Balance (in units) at Mar. 31, 2016								104,169,573
Beginning Balance at Mar. 31, 2016	$ 1,694,065		$ (157)	$ 37,707	$ (50,811)	$ 1,707,326
Increase (Decrease) in Partnership Capital
Distributions	(86,457)			(2,750)	(141)	(83,566)
Contributions	524			966	59	(501)
Business combinations (in units)								218,617
Business combinations	3,969				0	3,969
Purchase of noncontrolling interest (Notes 4 and 15)	(12,817)			(12,602)		(215)
Equity issued pursuant to incentive compensation plan (in units)								2,340,082
Equity issued pursuant to incentive compensation plan	54,781				0	54,781
Common units issued, net of offering costs (in units)								524,000
Common units issued, net of offering costs	9,383				0	9,383
Allocation of value to beneficial conversion feature of Class A convertible preferred units		$ 131,534					$ 131,534
Issuance of warrants	48,550					48,550
Accretion of beneficial conversion feature of Class A convertible preferred units		$ (3,808)					$ (3,808)
Net (loss) income	116,095			5,774	158	110,163
Other comprehensive loss	(485)		(485)
Other	(20)			0		(20)
Ending Balance (in units) at Sep. 30, 2016								107,252,272
Ending Balance at Sep. 30, 2016	1,955,314		(642)	29,095	(50,735)	1,977,596
Increase (Decrease) in Partnership Capital
Business combinations	$ 3,969
Common units issued, net of offering costs (in units)	524,000
Net (loss) income	$ (66,658)
Other comprehensive loss	(333)
Ending Balance (in units) at Sep. 30, 2016								107,252,272
Ending Balance at Sep. 30, 2016	$ 1,955,314		$ (642)	$ 29,095	$ (50,735)	$ 1,977,596

Unaudited Condensed Consolidat7

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
OPERATING ACTIVITIES:
Net (loss) income	$ 116,095	$ (31,107)
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation and amortization, including amortization of debt issuance costs	108,133	124,551
Gain on early extinguishment or revaluation of liabilities	(30,890)	(27,104)
Non-cash equity-based compensation expense	32,994	51,482
(Gain) loss on disposal or impairment of assets, net	(203,467)	1,712
Provision for doubtful accounts	(122)	3,046
Net commodity derivative loss (gain)	44,966	(44,534)
Equity in earnings of unconsolidated entities	(447)	(11,150)
Distributions of earnings from unconsolidated entities	42	11,593
Revaluation of investments	14,365	0
Other	(485)	(8)
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable-trade and affiliates	(54,069)	322,230
Inventories	(151,507)	34,333
Other current and noncurrent assets	(44,798)	(7,322)
Accounts payable-trade and affiliates	90,496	(272,322)
Other current and noncurrent liabilities	22,295	18,695
Net cash (used in) provided by operating activities	(56,399)	174,095
INVESTING ACTIVITIES:
Capital expenditures	(159,680)	(222,276)
Purchases of pipeline capacity allocations	(41,953)	0
Acquisitions of businesses, including acquired working capital, net of cash acquired	(113,297)	(150,546)
Cash flows from commodity derivatives	(25,015)	43,032
Proceeds from sales of assets	396	3,567
Proceeds from sale of TLP common units	112,370	0
Investments in unconsolidated entities	0	(6,926)
Distributions of capital from unconsolidated entities	5,233	8,207
Loan for natural gas liquids facility	0	(3,913)
Payments on loan for natural gas liquids facility	4,324	3,546
Loan to affiliate	(1,700)	(15,621)
Payments on loan to affiliate	655	0
Payment to terminate development agreement	(16,875)	0
Net cash used in investing activities	(235,542)	(340,930)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	770,000	1,354,700
Payments on revolving credit facilities	(595,500)	(1,006,600)
Repurchases of senior notes	(15,129)	0
Payments on other long-term debt	(4,423)	(2,344)
Debt issuance costs	(320)	(1,380)
Contributions from partners	(442)	45
Contributions from noncontrolling interest owners	966	6,613
Distributions to partners	(83,707)	(154,824)
Distributions to noncontrolling interest owners	(2,750)	(17,780)
Proceeds from sale of convertible preferred units and warrants, net of offering costs	235,018	0
Proceeds from sale of common units, net of offering costs	9,383	0
Payments for the early extinguishment of liabilities	(25,884)	0
Taxes paid on behalf of equity incentive plan participants	0	(19,083)
Common unit repurchases	0	(3,650)
Other	(20)	(112)
Net cash provided by financing activities	287,192	155,585
Net decrease in cash and cash equivalents	(4,749)	(11,250)
Cash and cash equivalents, beginning of period	28,176	41,303
Cash and cash equivalents, end of period	$ 23,427	$ 30,053

Organization and Operations

Organization and Operations	6 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Operations	Organization and Operations NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership . NGL Energy Holdings LLC serves as our general partner. At September 30, 2016 , our operations include: • Our Crude Oil Logistics segment, the assets of which include owned and leased crude oil storage terminals and pipeline injection stations, a fleet of owned trucks and trailers, a fleet of owned and leased railcars, a fleet of owned barges and towboats, and interests in two crude oil pipelines, purchases crude oil from producers and transports it to refineries or for resale at owned and leased pipeline injection stations, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs. • Our Water Solutions segment, the assets of which include water pipelines, water treatment and disposal facilities, washout facilities, and solid waste disposal facilities, provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production and for the disposal of solids such as tank bottoms and drilling fluids and performs truck washouts. In addition, our Water Solutions segment sells the recovered hydrocarbons that result from performing these services. • Our Liquids segment supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada using its leased underground storage and fleet of leased railcars, markets regionally through its 18 owned terminals throughout the United States, and provides terminaling and storage services at its salt dome storage facility in Utah. • Our Retail Propane segment sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain resellers in 27 states and the District of Columbia. • Our Refined Products and Renewables segment, which conducts gasoline, diesel, ethanol, and biodiesel marketing operations, purchases refined petroleum and renewable products primarily in the Gulf Coast, Southeast and Midwest regions of the United States and schedules them for delivery at various locations. Recent Developments On February 1, 2016, we completed the sale of our general partner interest in TransMontaigne Partners L.P. (“TLP”) to an affiliate of ArcLight Capital Partners (“ArcLight”). As a result, on February 1, 2016, we deconsolidated TLP and began to account for our limited partner investment in TLP using the equity method of accounting. See Note 2 for a discussion of the sale. As TLP was previously a consolidated entity, our condensed consolidated statements of operations for the three months and six months ended September 30, 2015 included three months and six months, respectively, of TLP’s operations and income attributable to the noncontrolling interests of TLP. On April 1, 2016, we sold all of the TLP common units we owned to ArcLight . See Note 2 for a discussion of the sale.

Significant Accounting Policies

Significant Accounting Policies	6 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies Basis of Presentation The accompanying unaudited condensed consolidated financial statements include our accounts and those of our controlled subsidiaries. Intercompany transactions and account balances have been eliminated in consolidation. Investments we cannot 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. We have included our proportionate share of assets, liabilities, and expenses related to this pipeline in our unaudited condensed consolidated financial statements. Our unaudited condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim consolidated financial information in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the unaudited condensed consolidated financial statements exclude certain information and notes required by GAAP for complete annual consolidated financial statements. However, we believe that the disclosures made are adequate to make the information presented not misleading. The unaudited condensed consolidated financial statements include all adjustments that we consider necessary for a fair presentation of our consolidated financial position and results of operations for the interim periods presented. Such adjustments consist only of normal recurring items, unless otherwise disclosed in this Quarterly Report. The unaudited condensed consolidated balance sheet at March 31, 2016 was derived from our audited consolidated financial statements for the fiscal year ended March 31, 2016 included in our Annual Report on Form 10-K (“Annual Report”). As previously reported, subsequent to the issuance of certain previously issued financial statements, in the fourth quarter of fiscal year 2016, we determined that there were errors in those financial statements from not recording certain contingent consideration liabilities related to royalty agreements assumed as part of acquisitions in our Water Solutions segment. The effect of the error was material to the financial statements for each of the first three quarters of the fiscal year ended March 31, 2016, so those quarters have been restated for the effects of the error correction. We have restated our previously issued condensed consolidated statements of operations and condensed consolidated statements of comprehensive loss for the three months and six months ended September 30, 2015 and condensed consolidated statement of cash flows for the six months ended September 30, 2015 . See Note 17 in our Annual Report for a summary of the impact of the error correction for the three months and six months ended September 30, 2015 . These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report. Due to the seasonal nature of certain of our operations and other factors, the results of operations for interim periods are not necessarily indicative of the results of operations to be expected for future periods or for the full fiscal year ending March 31, 2017 . 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 condensed consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations, 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 assets, the fair value of asset retirement obligations, the value of equity-based compensation, and accruals for various commitments and contingencies, among others. Although we believe these estimates are reasonable, actual results could differ from those estimates. Significant Accounting Policies Our significant accounting policies are consistent with those disclosed in Note 2 of our audited consolidated financial statements included in our Annual Report. 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. 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 data (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 condensed consolidated balance sheets except for certain contracts that qualify for the normal purchase and normal sale election. Under this accounting policy election, we do not record the 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 commodity derivative instruments that do not qualify as normal purchases and normal sales (whether cash transactions or non-cash mark-to-market adjustments) are reported within cost of sales in our condensed 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. 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 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 risk 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. Revenue Recognition We record product sales revenues when title to the product transfers to the purchaser, which typically occurs when the purchaser receives the product. We record terminaling, transportation, storage, and service revenues when the service is performed, and we record tank and other rental revenues over the lease term. Revenues for our Water Solutions segment are recognized when we obtain the wastewater at our treatment and disposal facilities. 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 condensed consolidated statements of operations. We enter into certain contracts whereby we agree to purchase product from a counterparty and sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into at the same time and in contemplation of each other, we record the revenues for these transactions net of cost of sales. Revenues during the three months ended September 30, 2016 and 2015 include $1.2 million and $1.5 million , respectively, and revenues during the six months ended September 30, 2016 and 2015 include $2.5 million and $2.9 million , respectively, associated with the amortization of a liability recorded in the acquisition accounting for an acquired business related to certain out-of-market revenue contracts. Supplemental Cash Flow Information Non-cash investing and financing activities and supplemental disclosures of cash flow information are as follows for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) NON-CASH INVESTING AND FINANCING ACTIVITIES: Value of common units issued in business combinations $ 3,969 $ — $ 3,969 $ 11,367 SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION: Cash interest paid $ 29,711 $ 26,323 $ 58,869 $ 57,495 Income taxes paid (net of income tax refunds) 71 533 1,755 4,616 Cash flows from settlements of commodity derivative instruments are included in investing activities in our condensed consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in operating activities in our condensed consolidated statements of cash flows. Inventories We value our inventories at the lower of cost or market, with cost determined using either the weighted-average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage. Market is determined based on estimated replacement cost using prices at the end of the reporting period. In performing this analysis, we consider fixed-price forward commitments and the opportunity to transfer propane inventory from our wholesale Liquids business to our Retail Propane business to sell the inventory in retail markets. Inventories consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Crude oil $ 86,495 $ 84,030 Natural gas liquids: Propane 73,704 28,639 Butane 44,929 8,461 Other 5,936 6,011 Refined products: Gasoline 126,821 80,569 Diesel 138,245 99,398 Renewables 34,328 52,458 Other 9,882 8,240 Total $ 520,340 $ 367,806 Investments in Unconsolidated Entities Investments we cannot control, but can exercise significant influence over, are 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 condensed consolidated balance sheets; instead, our ownership interests are reported within investments in unconsolidated entities on our condensed 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 historical net book value of the net assets of the investee. We use the cumulative earnings approach to classify distributions received from unconsolidated entities as either operating activities or investing activities in our condensed consolidated statements of cash flows. On April 1, 2016, we sold all of the TLP common units we owned to ArcLight for approximately $112.4 million in cash and recorded a gain on disposal of $104.1 million during the six months ended September 30, 2016 . Our investments in unconsolidated entities consist of the following at the dates indicated: Entity Segment Ownership Date Acquired September 30, 2016 March 31, 2016 (in thousands) Glass Mountain (1) Crude Oil Logistics 50% December 2013 $ 174,364 $ 179,594 Ethanol production facility Refined Products and Renewables 19% December 2013 13,507 12,570 Water treatment and disposal facility Water Solutions 50% August 2015 2,235 2,238 Retail propane company Retail Propane 50% April 2015 556 972 TLP (2) Refined Products and Renewables 0% July 2014 — 8,301 Water supply company (3) Water Solutions 100% June 2014 — 15,875 Total $ 190,662 $ 219,550 (1) When we acquired Gavilon, LLC, (“Gavilon Energy”), we recorded the investment in Glass Mountain Pipeline, LLC (“Glass Mountain”), which owns a crude oil pipeline in Oklahoma, at fair value. Our investment in Glass Mountain exceeds our proportionate share of the historical net book value of Glass Mountain’s net assets by $73.6 million at September 30, 2016 . This difference relates primarily to goodwill and customer relationships. (2) On April 1, 2016, we sold all of the TLP common units we owned. (3) On June 3, 2016, we acquired the remaining 65% ownership interest in the water supply company , and as a result, the water supply company is now consolidated in our condensed consolidated financial statements (see Note 4 ). Other Noncurrent Assets Other noncurrent assets consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Loan receivable (1) $ 44,957 $ 49,827 Tank bottoms (2) 42,044 42,044 Line fill (3) 35,013 35,060 Other 95,725 49,108 Total $ 217,739 $ 176,039 (1) Represents a loan receivable associated with our financing of the construction of a natural gas liquids facility to be utilized by a third party . (2) 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. At September 30, 2016 and March 31, 2016 , tank bottoms held in third party terminals consisted of 366,212 barrels and 366,212 barrels of refined products, respectively. Tank bottoms held in terminals we own are included within property, plant and equipment (see Note 5 ). (3) Represents minimum volumes of crude oil we are required to leave on certain third-party owned pipelines under long-term shipment commitments. At September 30, 2016 and March 31, 2016 , line fill consisted of 486,473 barrels and 487,104 barrels of crude oil, respectively. Accrued Expenses and Other Payables Accrued expenses and other payables consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Accrued compensation and benefits $ 19,322 $ 40,517 Excise and other tax liabilities 56,147 59,455 Derivative liabilities 31,959 28,612 Accrued interest 19,594 20,543 Product exchange liabilities 7,045 5,843 Deferred gain on sale of general partner interest in TLP 30,113 30,113 Other 20,454 29,343 Total $ 184,634 $ 214,426 Sale of General Partner Interest in TLP As previously reported, on February 1, 2016, we completed the sale of our general partner interest in TLP to ArcLight and deferred a portion of the gain on the sale and will recognize this amount over our future lease payment obligations, which is approximately seven years . During the three months and six months ended September 30, 2016 , we recognized $7.6 million and $15.1 million , respectively, of the deferred gain in our condensed consolidated statements of operations. Within our condensed consolidated balance sheet, the current portion of the deferred gain, $30.1 million , is recorded in accrued expenses and other payables and the long-term portion, $154.4 million , is recorded in other noncurrent liabilities. Noncontrolling Interests We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our condensed consolidated financial statements represents the other owners’ interests in these entities. Business Combination Measurement Period We record the assets acquired and liabilities assumed in a business combination at their acquisition date fair values. 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 value of the assets acquired and liabilities assumed in a business combination. As discussed in Note 4 , certain of our acquisitions are still within this measurement period, and as a result, the acquisition date fair values we have recorded for the assets acquired and liabilities assumed are subject to change. Also, as discussed in Note 4 , we made certain adjustments during the three months ended September 30, 2016 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the fiscal year ended March 31, 2016 . In September 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2015-16, “Simplifying the Accounting Adjustments for Measurement-Period Adjustments.” The ASU requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. This ASU requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. The ASU was effective for the Partnership beginning April 1, 2016, and required a prospective method of adoption. Reclassifications We have reclassified certain prior period financial statement information to be consistent with the classification methods used in the current fiscal year. These reclassifications did not impact previously reported amounts of equity, net income, or cash flows. Recent Accounting Pronouncements 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. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectibility of the reported amount. The ASU is effective for the Partnership beginning April 1, 2020, and requires a modified retrospective method of adoption, although early adoption is permitted. We are in the process of assessing the impact of this ASU on our consolidated financial statements. In February 2016, the FASB issued ASU No. 2016-02, “Leases.” The ASU will replace previous lease accounting guidance in GAAP. The ASU requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. The ASU retains a distinction between finance leases and operating leases. The ASU is effective for the Partnership beginning April 1, 2019, and requires a modified retrospective method of adoption. We are in the process of assessing the impact of this ASU on our consolidated financial statements. In July 2015, the FASB issued ASU No. 2015-11, “Simplifying the Measurement of Inventory.” The ASU requires that inventory within the scope of the guidance be measured at the lower of cost or net realizable value. The ASU is effective for the Partnership beginning April 1, 2017, and requires a prospective method of adoption, although early adoption is permitted. We do not expect the adoption of this ASU to have a material impact on our consolidated financial position or results of operations. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers.” The ASU will replace most existing revenue recognition guidance in GAAP. The core principle of this ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU is effective for the Partnership beginning April 1, 2018, and allows for both full retrospective and modified retrospective methods of adoption. We are in the process of determining the method of adoption and assessing the impact of this ASU on our consolidated financial statements.

Income (Loss) Per Common Unit

Income (Loss) Per Common Unit	6 Months Ended
	Sep. 30, 2016
Earnings Per Unit [Abstract]
Income (Loss) Per Common Unit	Income (Loss) Per Common Unit Our income (loss) per common unit is as follows for the periods indicated: As Restated As Restated Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands, except unit and per unit amounts) Net (loss) income $ (66,658 ) $ (6,100 ) $ 116,095 $ (31,107 ) Less: Net loss (income) attributable to noncontrolling interests 59 (3,497 ) (5,774 ) (7,847 ) Net (loss) income attributable to NGL Energy Partners LP (66,599 ) (9,597 ) 110,321 (38,954 ) Less: Distributions to preferred unitholders (8,668 ) — (12,052 ) — Less: Net loss (income) allocated to general partner (1) 45 (16,185 ) (158 ) (31,559 ) Net (loss) income allocated to common unitholders $ (75,222 ) $ (25,782 ) $ 98,111 $ (70,513 ) Basic (loss) income per common unit $ (0.71 ) $ (0.25 ) $ 0.93 $ (0.67 ) Diluted (loss) income per common unit $ (0.71 ) $ (0.25 ) $ 0.91 $ (0.67 ) Basic weighted average common units outstanding 106,186,389 105,189,463 105,183,556 104,542,427 Diluted weighted average common units outstanding 106,186,389 105,189,463 107,997,549 104,542,427 (1) Net income (loss) allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are discussed in Note 11 . The diluted weighted average common units outstanding for the six months ended September 30, 2016 included 2,803,436 warrants and 10,621 performance units that were considered dilutive for the period. For the six months ended September 30, 2016 and 2015 , the restricted units were considered antidilutive. For the six months ended September 30, 2016 , the convertible preferred units were considered antidilutive.

Acquisitions

Acquisitions	6 Months Ended
	Sep. 30, 2016
Business Combinations [Abstract]
Acquisitions	Acquisitions Fiscal Year Ending March 31, 2017 Water Solutions Facilities During the six months ended September 30, 2016 , we acquired three water solutions facilities and paid $26.9 million of cash. In addition, we have recorded contingent consideration liabilities within accrued expenses and other payables and other noncurrent liabilities related to future royalty payments due to the sellers of one of these facilities. We estimated the contingent consideration based on the contracted royalty rate, which is a flat rate per disposal barrel and percentage of oil revenues, multiplied by the expected disposal volumes and oil revenue for the expected useful life of the facility and disposal well. This amount was then discounted to present value using our weighted average cost of capital plus a premium representative of the uncertainty associated with the expected disposal volumes and oil revenue. As of the acquisition date, we recorded a contingent liability of $2.6 million . Also, for one of these facilities, we have recorded a liability for contingent royalty payments. We estimated the contingent royalty payments based on the contracted royalty rate, which is a flat rate per disposal barrel, multiplied by the expected disposal volumes for the expected useful life of the facility and disposal well. This amount was then discounted to present value using our weighted average cost of capital plus a premium representative of the uncertainty associated with the expected disposal volumes. As of the acquisition date, we recorded a contingent royalty liability of $8.2 million . We are in the process of identifying and determining the fair values of the assets acquired and liabilities assumed for these water solutions facilities, and as a result, the estimates of fair value at September 30, 2016 are subject to change. We expect to complete this process before we issue our financial statements for the three months ending June 30, 2017. The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Property, plant and equipment $ 15,021 Goodwill 18,933 Intangible assets 3,878 Current liabilities (1,239 ) Other noncurrent liabilities (9,697 ) Fair value of net assets acquired $ 26,896 Goodwill represents a premium paid to expand the number of our disposal sites in an oilfield production basin currently serviced by us, thereby enhancing our competitive position as a provider of disposal services in this oilfield production basin. We estimate that all of the goodwill will be deductible for federal income tax purposes. Acquisition of Remaining Interest in Water Solutions Facilities On September 15, 2016, we acquired the remaining 25% ownership interest in three water solutions facilities and paid $10.0 million of cash. The acquisition of the remaining interest was accounted for as an equity transaction, no gain or loss was recorded and the carrying value of the noncontrolling interest was adjusted to reflect the change in ownership interest of the subsidiary. As of the date of the transaction, the 25% interest had a carrying value of $7.4 million . Water Pipeline Company As discussed below, on January 7, 2016, we acquired a 57.125% interest in an existing produced water pipeline company operating in the Delaware Basin portion of West Texas. On June 3, 2016, we acquired an additional 24.5% interest in this water pipeline company as part of the purchase and sale agreement discussed in Note 15 . As we control this entity (and continue to retain our controlling financial interest), the acquisition of the additional interest was accounted for as an equity transaction, no gain or loss was recorded and the carrying value of the noncontrolling interest was adjusted to reflect the change in ownership interest of the subsidiary. As of the date of the transaction, the 24.5% interest had a carrying value of $5.2 million . Water Supply Company On June 3, 2016, we acquired the remaining 65% ownership interest in a water supply company (see Note 2 ). In exchange for this additional interest, we paid $1.0 million of cash and assumed an outstanding note payable, which relates to money this entity previously borrowed from us. Prior to the completion of this transaction, we accounted for our previously held 35% ownership interest of this water supply company using the equity method of accounting (see Note 2 ). As we now own a controlling interest in this entity, we revalued our previously held 35% ownership interest to fair value of $0.8 million and recorded a loss of $14.9 million , which is recorded within revaluation of investments in our condensed consolidated statement of operations. As the amount paid (cash plus the fair value of our previously held ownership interest) was less than the fair value of the assets acquired and liabilities assumed, we recorded a gain on bargain purchase of $0.6 million within revaluation of investments in our condensed consolidated statement of operations. We are in the process of identifying and determining the fair values of the assets acquired and liabilities assumed in this business combination, and as a result, the estimates of fair value at September 30, 2016 are subject to change. We expect to complete this process before we issue our financial statements for the three months ending June 30, 2017. The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Current assets $ 1,713 Property, plant and equipment 8,874 Intangible asset 14,472 Current liabilities (2,765 ) Notes payable-intercompany (19,900 ) Fair value of net assets acquired $ 2,394 Retail Propane Businesses During the six months ended September 30, 2016 , we acquired three retail propane businesses and paid $72.1 million of cash and issued 218,617 common units, valued at $4.0 million , in exchange for these assets and operations. In connection with the issuance of the common units, we issued 219 general partner units to our general partner and less than $0.1 million in order to maintain its 0.1% general partner interest in us. The agreement for these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair values of the assets acquired and liabilities assumed in these business combinations, and as a result, the estimates of fair value at September 30, 2016 are subject to change. We expect to complete this process before we issue our financial statements for the three months ending June 30, 2017. The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Current assets $ 6,282 Property, plant and equipment 30,576 Goodwill 9,419 Intangible assets 36,950 Current liabilities (5,555 ) Other noncurrent liabilities (1,587 ) Fair value of net assets acquired $ 76,085 Fiscal Year Ended March 31, 2016 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 value of the assets acquired and liabilities assumed in a business combination. Water Pipeline Company During the six months ended September 30, 2016 , we finalized the purchase price accounting for the 57.125% interest acquired in a water pipeline company on January 7, 2016. During the three months ended June 30, 2016, we recorded an adjustment to reclassify approximately $1.1 million from property, plant and equipment to intangible assets, in order to present the fair value of the acquired rights-of-way as an indefinite-lived asset, which is consistent with our historical accounting policies. During the six months ended September 30, 2016 , we recorded an adjustment of $0.3 million to other noncurrent liabilities to recognize an asset retirement obligation related to assets that we acquired. This adjustment also increased goodwill by the same amount. There have been no other adjustments to the fair value of assets acquired and liabilities assumed which were disclosed in our Annual Report. Delaware Basin Water Solutions Facilities During the three months ended June 30, 2016, we finalized the purchase price accounting for the four saltwater disposal facilities and a 50% interest in an additional saltwater disposal facility in the Delaware Basin of the Permian Basin in Texas we acquired on August 24, 2015. There have been no adjustments to the fair value of assets acquired and liabilities assumed which were disclosed in our Annual Report. Water Solutions Facilities During the three months ended June 30, 2016, we finalized the purchase price accounting for nine water facilities acquired under the development agreement during the fiscal year ended March 31, 2016 . During the three months ended June 30, 2016, we received additional information and recorded an adjustment of $0.7 million to property, plant and equipment to recognize the fair value of additional assets that we acquired. This adjustment also reduced goodwill by the same amount. In addition, we paid $1.0 million in cash to the seller during the three months ended June 30, 2016 for consideration that was held back at the acquisition date, which we recorded as a liability to accrued expenses and other payables. Retail Propane Businesses During the six months ended September 30, 2016 , we finalized the purchase price accounting for five retail propane businesses we acquired during the fiscal year ended March 31, 2016 and paid $0.3 million in cash to a seller during the six months ended September 30, 2016 for consideration that was held back at the acquisition date, which we recorded as a liability to accrued expenses and other payables.

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Sep. 30, 2016
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: Description Estimated September 30, 2016 March 31, 2016 (in thousands) Natural gas liquids terminal and storage assets 2–30 years $ 168,754 $ 169,758 Refined products terminal assets and equipment 20 years 6,844 6,844 Retail propane equipment 2–30 years 227,442 201,312 Vehicles and railcars 3–25 years 194,291 185,547 Water treatment facilities and equipment 3–30 years 535,255 508,239 Crude oil tanks and related equipment 2–40 years 140,245 137,894 Barges and towboats 5–40 years 89,973 86,731 Information technology equipment 3–7 years 42,218 38,653 Buildings and leasehold improvements 3–40 years 123,005 118,885 Land 50,132 47,114 Tank bottoms 20,105 20,355 Other 3–30 years 56,450 11,699 Construction in progress 425,066 383,032 2,079,780 1,916,063 Accumulated depreciation (324,364 ) (266,491 ) Net property, plant and equipment $ 1,755,416 $ 1,649,572 The following table summarizes depreciation expense and capitalized interest expense for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Depreciation expense $ 28,703 $ 34,469 $ 56,357 $ 70,264 Capitalized interest expense 1,069 549 4,804 690 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. The following table summarizes the tank bottoms included in the table above at the dates indicated: September 30, 2016 March 31, 2016 Product Volume Value Volume Value Crude oil 229 $ 19,120 231 $ 19,348 Other 24 985 24 1,007 Total $ 20,105 $ 20,355 Loss on Disposal of Assets During the three months and six months ended September 30, 2016 , we recorded losses of $8.5 million and $10.8 million , respectively, due primarily to the sales and write-down of certain assets in our Crude Oil Logistics and Water Solutions segments. During the three months and six months ended September 30, 2015 , we recorded losses of $1.1 million and $1.7 million , respectively, primarily due to the sales of certain assets in our Crude Oil Logistics and Water Solutions segments. These losses are reported within loss (gain) on disposal or impairment of assets, net in our condensed consolidated statements of operations.

Goodwill

Goodwill	6 Months Ended
	Sep. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The following table summarizes changes in goodwill by segment during the six months ended September 30, 2016 : Crude Oil Water Liquids Retail Refined Total (in thousands) Balances at March 31, 2016 $ 579,846 $ 290,915 $ 266,046 $ 127,428 $ 51,127 $ 1,315,362 Revisions to acquisition accounting (Note 4) — (419 ) — (2 ) — (421 ) Acquisitions (Note 4) — 18,933 — 9,419 — 28,352 Adjustment to initial impairment estimate — 124,662 — — — 124,662 Balances at September 30, 2016 $ 579,846 $ 434,091 $ 266,046 $ 136,845 $ 51,127 $ 1,467,955 Goodwill Adjustment to Initial Impairment Estimate During the three months ended March 31, 2016, we recorded a preliminary goodwill impairment charge of $380.2 million . During the three months ended June 30, 2016, we finalized our goodwill impairment analysis, with the assistance of a third party valuation firm. As a result of finalizing our analysis, we determined that we needed to reverse $124.7 million of the previously recorded goodwill impairment recorded during the three months ended March 31, 2016. The reversal was due primarily to the change in the fair value of our customer relationship intangible assets. With the assistance of the third party valuation firm, inputs such as revenue growth rates and attrition rates related to existing customers were refined and resulted in a lower fair value allocated to customer relationships than in our preliminary calculation. We recorded the reversal within loss (gain) on disposal or impairment of assets, net in our condensed consolidated statement of operations.

Intangible Assets

Intangible Assets	6 Months Ended
	Sep. 30, 2016
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets Our intangible assets consist of the following at the dates indicated: September 30, 2016 March 31, 2016 Description Amortizable Lives Gross Carrying Accumulated Net Gross Carrying Accumulated Net (in thousands) Amortizable: Customer relationships 3–20 years $ 883,896 $ 274,111 $ 609,785 $ 852,118 $ 233,838 $ 618,280 Pipeline capacity rights 30 years 161,589 8,957 152,632 119,636 6,559 113,077 Water facility development agreement 5 years — — — 14,000 7,700 6,300 Executory contracts and other agreements 2–30 years 22,713 19,699 3,014 23,920 21,075 2,845 Non-compete agreements 2–32 years 31,784 15,101 16,683 20,903 13,564 7,339 Trade names 1–10 years 15,439 12,882 2,557 15,439 12,034 3,405 Debt issuance costs (1) 3 years 39,977 25,564 14,413 39,942 22,108 17,834 Total amortizable 1,155,398 356,314 799,084 1,085,958 316,878 769,080 Non-amortizable: Customer commitments 310,000 — 310,000 310,000 — 310,000 Rights-of-way and easements 47,721 — 47,721 47,190 — 47,190 Water rights 14,472 — 14,472 — — — Trade names 18,870 — 18,870 22,620 — 22,620 Total non-amortizable 391,063 — 391,063 379,810 — 379,810 Total $ 1,546,461 $ 356,314 $ 1,190,147 $ 1,465,768 $ 316,878 $ 1,148,890 (1) Includes debt issuance costs related to the Revolving Credit Facility (as defined herein). Debt issuance costs related to fixed-rate notes are reported as a reduction of the carrying amount of long-term debt. The weighted-average remaining amortization period for intangible assets is approximately 8.6 years . Write off of Intangible Assets As a result of terminating the development agreement in the Water Solutions segment (see Note 15 ), we incurred a loss of $5.8 million to write off the water facility development agreement. During the six months ended September 30, 2016 , we wrote-off $5.2 million related to the value of an indefinite-lived trade name intangible asset in conjunction with finalizing our goodwill impairment analysis (see Note 6 ). These losses are reported within loss (gain) on disposal or impairment of assets, net in our condensed consolidated statement of operations. Amortization expense is as follows for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, Recorded In 2016 2015 2016 2015 (in thousands) Depreciation and amortization $ 21,900 $ 22,291 $ 43,152 $ 46,328 Cost of sales 1,749 1,700 3,345 3,401 Interest expense 1,731 1,470 3,456 2,954 Total $ 25,380 $ 25,461 $ 49,953 $ 52,683 Expected amortization of intangible assets, exclusive of assets that are not yet amortizable, is as follows (in thousands): Year Ending March 31, 2017 (six months) $ 51,028 2018 98,717 2019 89,701 2020 82,185 2021 69,422 Thereafter 408,031 Total $ 799,084

Long-Term Debt

Long-Term Debt	6 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Our long-term debt consists of the following at the dates indicated: September 30, 2016 March 31, 2016 Face Unamortized Book Face Unamortized Book (in thousands) Revolving credit facility: Expansion capital borrowings $ 1,312,000 $ — $ 1,312,000 $ 1,229,500 $ — $ 1,229,500 Working capital borrowings 710,500 — 710,500 618,500 — 618,500 5.125% Notes due 2019 383,467 (3,871 ) 379,596 388,467 (4,681 ) 383,786 6.875% Notes due 2021 369,063 (6,433 ) 362,630 388,289 (7,545 ) 380,744 6.650% Notes due 2022 250,000 (3,055 ) 246,945 250,000 (3,166 ) 246,834 Other long-term debt 59,506 (123 ) 59,383 61,488 (108 ) 61,380 3,084,536 (13,482 ) 3,071,054 2,936,244 (15,500 ) 2,920,744 Less: Current maturities 8,046 — 8,046 7,907 — 7,907 Long-term debt $ 3,076,490 $ (13,482 ) $ 3,063,008 $ 2,928,337 $ (15,500 ) $ 2,912,837 (1) Debt issuance costs related to the Revolving Credit Facility (as defined herein) are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt. Amortization expense for debt issuance costs related to our notes due in 2019, 2021 and 2022 and other long-term debt was $1.0 million and $0.8 million during the three months ended September 30, 2016 and 2015 , respectively, and $1.8 million and $1.6 million during the six months ended September 30, 2016 and 2015 , respectively. Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2017 (six months) $ 1,619 2018 3,229 2019 3,226 2020 2,236 2021 1,827 Thereafter 1,345 Total $ 13,482 Credit Agreement We have entered into a credit agreement (as amended, the “Credit Agreement”) with a syndicate of banks. The Credit Agreement includes a revolving credit facility to fund working capital needs (the “Working Capital Facility”) and a revolving credit facility to fund acquisitions and expansion projects (the “Expansion Capital Facility,” and together with the Working Capital Facility, the “Revolving Credit Facility”). At September 30, 2016 , our Revolving Credit Facility had a total capacity of $2.484 billion . Our Revolving Credit Facility has an “accordion” feature that allows us to increase the capacity by $150 million if new lenders wish to join the syndicate or if current lenders wish to increase their commitments. The Expansion Capital Facility had a total capacity of $1.446 billion for cash borrowings at September 30, 2016 . At that date, we had outstanding borrowings of $1.312 billion on the Expansion Capital Facility. The Working Capital Facility had a total capacity of $1.038 billion for cash borrowings and letters of credit at September 30, 2016 . At that date, we had outstanding borrowings of $710.5 million and outstanding letters of credit o f $75.3 million on the Working Capital Facility. Amounts outstanding for letters of credit are not recorded as long-term debt on our condensed consolidated balance sheets, although they decrease our borrowing capacity under the Working Capital Facility. The capacity available under the Working Capital Facility may be limited by a “borrowing base” (as defined in the Credit Agreement), which is calculated based on the value of certain working capital items at any point in time. The commitments under the Credit Agreement expire on November 5, 2018. We have the right to prepay outstanding borrowings under the Credit Agreement without incurring any penalties, and prepayments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings. All borrowings under the Credit Agreement bear interest, at our option, at either (i) an alternate base rate plus a margin of 0.50% to 1.75% per year or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.75% per year. The applicable margin is determined based on our consolidated leverage ratio (as defined in the Credit Agreement). At September 30, 2016 , the borrowings under the Credit Agreement had an average interest rate of 2.83% , calculated as the LIBOR rate of 0.53% plus a margin of 2.25% for LIBOR borrowings and the prime rate of 3.50% plus a margin of 1.25% on alternate base rate borrowings. At September 30, 2016 , the interest rate in effect on letters of credit was 2.25% . Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused capacity. The Revolving Credit Facility is secured by substantially all of our assets. The Credit Agreement also specifies that our leverage ratio cannot be more than 4.75 to 1 and that our interest coverage ratio cannot be less than 2.75 to 1 at any quarter end. At September 30, 2016 , our leverage ratio was approximately 4.15 to 1 and our interest coverage ratio was approximately 4.60 to 1 . At September 30, 2016 , we were in compliance with the covenants under the Credit Agreement. 2019 Notes On July 9, 2014, we issued $400.0 million of 5.125% Senior Notes Due 2019 (the “2019 Notes”). During the three months ended June 30, 2016 , we repurchased $5.0 million of our 2019 Notes for an aggregate purchase price of $3.1 million (excluding payments of accrued interest). As a result, we recorded a gain on the early extinguishment of our 2019 Notes of $1.8 million (net of the write off of debt issuance costs of $0.1 million ). The 2019 Notes mature on July 15, 2019. Interest is payable on January 15 and July 15 of each year. We have the right to redeem the 2019 Notes before the maturity date, although we would be required to pay a premium for early redemption. At September 30, 2016 , we were in compliance with the covenants under the indenture governing the 2019 Notes. 2021 Notes On October 16, 2013, we issued $450.0 million of 6.875% Senior Notes Due 2021 (the “2021 Notes”). During the three months ended June 30, 2016 , we repurchased $19.2 million of our 2021 Notes for an aggregate purchase price of $12.0 million (excluding payments of accrued interest). As a result, we recorded a gain on the early extinguishment of our 2021 Notes of $6.8 million (net of the write off of debt issuance costs of $0.4 million ). The 2021 Notes mature on October 15, 2021. Interest is payable on April 15 and October 15 of each year. We have the right to redeem the 2021 Notes before the maturity date, although we would be required to pay a premium for early redemption. At September 30, 2016 , we were in compliance with the covenants under the indenture governing the 2021 Notes. 2022 Notes On June 19, 2012, we entered into a Note Purchase Agreement (as amended, the “Note Purchase Agreement”) whereby we issued $250.0 million of Senior Notes in a private placement (the “2022 Notes”). The 2022 Notes bear interest at a fixed rate of 6.65% , which is payable quarterly. The 2022 Notes are required to be repaid in semi-annual installments of $25.0 million beginning on December 19, 2017 and ending on the maturity date of June 19, 2022. We have the option to prepay outstanding principal, although we would incur a prepayment penalty. On September 30, 2016, we amended our Note Purchase Agreement which, among other things, changes the maximum allowable leverage ratio to match the maximum allowable leverage ratio and the calculation of such ratio under our Credit Agreement. Additionally, the amendment provides for an increase in interest charged should our leverage ratio exceed certain predetermined levels. The 2022 Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement. At September 30, 2016 , we were in compliance with the covenants under the Note Purchase Agreement. Other Long-Term Debt We have certain notes payable related to equipment financing. We have also executed various noninterest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. These instruments have a combined principal balance of $59.5 million at September 30, 2016 , and the interest rates on these instruments range from 1.17% to 7.08% per year. Debt Maturity Schedule The scheduled maturities of our long-term debt are as follows at September 30, 2016 : Year Ending March 31, Revolving 2019 2021 2022 Other Total (in thousands) 2017 (six months) $ — $ — $ — $ — $ 3,405 $ 3,405 2018 — — — 25,000 8,014 33,014 2019 2,022,500 — — 50,000 6,857 2,079,357 2020 — 383,467 — 50,000 6,372 439,839 2021 — — — 50,000 34,728 84,728 Thereafter — — 369,063 75,000 130 444,193 Total $ 2,022,500 $ 383,467 $ 369,063 $ 250,000 $ 59,506 $ 3,084,536

Income Taxes

Income Taxes	6 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
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 in 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 2013 to 2016 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 basis. 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 initial public offering. 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 condensed consolidated financial statements at September 30, 2016 or March 31, 2016 .

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Contingencies We are party to various claims, legal actions, and complaints arising in the ordinary course of business. In the opinion of our management, the ultimate resolution of these claims, legal actions, and complaints, after consideration of amounts accrued, insurance coverage, and other arrangements, is not expected to have a material adverse effect on our consolidated financial position, results of operations or cash flows. However, the outcome of such matters is inherently uncertain, and estimates of our liabilities may change materially as circumstances develop. Environmental Matters Our condensed consolidated balance sheet at September 30, 2016 includes a liability, measured on an undiscounted basis, of $2.2 million related to environmental matters, which is reported within accrued expenses and other payables. 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. As previously disclosed, the U.S. Environmental Protection Agency (“EPA”) had informed NGL Crude Logistics, LLC, formerly known as Gavilon, LLC (hereafter referred to as “Gavilon”) of alleged violations in 2011 by Gavilon of the Clean Air Act’s renewable fuel standards regulations (prior to its acquisition by NGL in December 2013). On October 4, 2016, the U.S. Department of Justice, acting at the request of the EPA, filed a civil complaint in the Northern District of Iowa against Gavilon and one of its then suppliers, Western Dubuque Biodiesel LLC (“Western Dubuque”). Consistent with the earlier allegations by the EPA, the civil complaint relates to transactions between Gavilon and Western Dubuque and the generation of biodiesel renewable identification numbers (“RINs”) sold by Western Dubuque to Gavilon in 2011. The complaint seeks an order declaring that the RINs generated by Western Dubuque be declared invalid, that the defendants retire and replace such RINs and that the defendants pay statutory civil penalties. Consistent with our position against the previous EPA allegations, we deny the allegations in this civil complaint and intend to vigorously defend ourselves in the civil action. However, at this time NGL is unable to determine the outcome of this action or its significance to us. 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 is a rollforward of our asset retirement obligation, which is reported within other noncurrent liabilities in our condensed consolidated balance sheets (in thousands): Balance at March 31, 2016 $ 5,574 Liabilities assumed in acquisitions 406 Accretion expense 207 Balance at September 30, 2016 $ 6,187 In addition to the obligations discussed above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. We do not believe the present value of these asset retirement obligations, under current laws and regulations, after taking into consideration the estimated lives of our facilities, is material to our consolidated financial position or results of operations. Operating Leases We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, railcars, and equipment. The following table summarizes future minimum lease payments under these agreements at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 67,837 2018 122,935 2019 101,047 2020 90,112 2021 80,457 Thereafter 135,486 Total $ 597,874 Rental expense relating to operating leases was $27.0 million and $33.3 million during the three months ended September 30, 2016 and 2015 , respectively, and $56.9 million and $67.1 million during the six months ended September 30, 2016 and 2015 , respectively. Pipeline Capacity Agreements We have executed noncancelable agreements with crude oil and refined products 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. The following table summarizes future minimum throughput payments under these agreements at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 26,008 2018 52,082 2019 52,170 2020 42,418 Total $ 172,678 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. The following table summarizes such commitments at September 30, 2016 : Volume Value (in thousands) Purchase commitments: Natural gas liquids fixed-price (gallons) 35,592 $ 18,710 Natural gas liquids index-price (gallons) 587,044 347,020 Crude oil fixed-price (barrels) 1,993 88,079 Crude oil index-price (barrels) 14,466 655,273 Sale commitments: Natural gas liquids fixed-price (gallons) 163,546 105,868 Natural gas liquids index-price (gallons) 414,042 317,983 Crude oil fixed-price (barrels) 3,415 152,584 Crude oil index-price (barrels) 12,953 637,731 We account for the contracts shown in the table above as normal purchases and normal sales. Under this accounting policy election, we do not record the 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 table above may have offsetting derivative contracts (as discussed in Note 12 ) or inventory positions (as discussed 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 condensed consolidated balance sheet and are not included in the table above. These contracts are included in the derivative disclosures in Note 12 , and represent $41.0 million of our prepaid expenses and other current assets and $29.6 million of our accrued expenses and other payables at September 30, 2016 .

Equity

Equity	6 Months Ended
	Sep. 30, 2016
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 and obligations. Our Distributions The following table summarizes distributions declared for the last three quarters: Date Declared Record Date Date Paid/Payable Amount Per Unit Amount Paid/Payable to Limited Partners Amount Paid/Payable to General Partner (in thousands) (in thousands) April 21, 2016 May 3, 2016 May 13, 2016 $ 0.3900 $ 40,626 $ 70 July 22, 2016 August 4, 2016 August 12, 2016 0.3900 41,146 71 October 20, 2016 November 4, 2016 November 14, 2016 0.3900 41,907 72 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 (“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 . On May 11, 2016, we received an initial $100 million (“initial closing date”) and Oaktree received 8,309,237 Preferred Units, and on June 24, 2016, we received the remaining $140 million (“second closing date”) and Oaktree received 11,632,932 Preferred Units. In addition, Oaktree received 4,375,112 warrants ( 1,822,963 at the initial closing date and 2,552,149 at the second closing date) to purchase common units at an exercise price of $0.01 per common unit. We will pay a cumulative, quarterly distribution in arrears at an annual rate of 10.75% on the Preferred Units then outstanding in cash, to the extent declared by the board of directors of our general partner. To the extent declared, such distributions will be paid for each such quarter within 45 days after each quarter end. On July 22, 2016 , we declared a pro rata distribution for the three months ended June 30, 2016 of $1.8 million which was paid to the holders of the Preferred Units on August 12, 2016 . On October 20, 2016 , we declared a distribution for the three months ended September 30, 2016 of $6.4 million to be paid to the holders of the Preferred Units on November 14, 2016 . If the Preferred Unit quarterly distribution is not made in full in cash for any quarter, the Preferred Unit distribution rate will increase by one quarter of a percentage point ( 0.25% ) per annum beginning with distributions for the first six -month period that a payment default is in effect, and will further increase by an additional one quarter of a percentage point ( 0.25% ) beginning with distributions for the next six -month period during which a payment default remains in effect. The deficiency rate shall not exceed 11.25% per annum; as long as the default is occurring, the amount of accrued but unpaid Preferred Unit quarterly distributions shall increase at an annual rate of 10.75% , compounded quarterly, until paid in full. The Preferred Units have no mandatory redemption date but are redeemable, at our election, any time after the first anniversary of the closing date. We have the right to redeem all of the outstanding Preferred Units at a price per Preferred Unit equal to the purchase price multiplied by the redemption multiple then in effect. The redemption multiple means (a) 140% for redemptions occurring on or after the first, but prior to the second anniversary of the closing date, (b) 115% for the redemptions occurring on or after the second, but prior to the third anniversary of the closing date, (c) 110% for redemptions occurring on or after the third, but prior to the eighth anniversary of the closing date and (d) 101% for redemptions occurring on or after the eighth anniversary of the closing date. At any time after the third anniversary of the initial closing date, the Preferred Unit holders shall have the right to convert all of the outstanding Preferred Units at a price per Preferred Unit equal to the purchase price multiplied by the conversion multiple then in effect, which may be settled in common units, cash or a combination, at our discretion. The conversion multiple means if our common units are trading at or above $12.035 (“the initial conversion price”), the conversion price is not adjusted. However, if the conversion price is less than the initial conversion price, the conversion price will be reset to the greater of (i) the adjusted volume weighted average price of our common units for the fifteen trading days immediately preceding the third anniversary of the closing date or (ii) $5.00 . Upon a change of control of the Partnership, each Preferred Unit holder shall have the right, at its election, to either (i) elect to have its Preferred Units converted to common units; (ii) if we are the surviving entity of such change of control, it can elect to continue to hold its Preferred Units; or (iii) require us to redeem its Preferred Units for cash equal to (a) prior to the first anniversary of the closing date, 140% of the unit purchase price; (b) on or after the first but prior to the second anniversary of the closing date, 130% of the unit purchase price; (c) on or after the second anniversary of the closing date, 120% of the unit purchase price; and (d) thereafter, 101% of the unit purchase price. In each case, this amount will include any accrued but unpaid distributions at the redemption date. Under the private placement agreement, we are required to file within 180 days of the initial closing date a registration statement registering the resales of common units issued or to be issued upon conversion of the Preferred Units or exercise of the warrants and have the registration statement declared effective within 360 days after the closing date. We are required to continue to maintain the effectiveness of the registration statement until all securities have been sold. If the registration statement is not effective before the deadline, then the Preferred Unit holders shall be entitled to liquidated damages. The liquidated damages, which would accrue daily, are an amount equal to 0.25% of the multiplier for the first 60 day period following the effectiveness deadline plus an additional 0.25% of the multiplier for each subsequent 30 day period (i.e. 0.50% for 61-90 days, 0.75% for 91-120 days and 1.00% thereafter) up to a maximum of 1.00% of the liquidated damage multiplier per 30 day period, until the registration statement becomes effective or the Preferred Units are sold. The warrants have an eight year term, after which unexercised warrants will expire. The holders of the warrants may convert one-third of the warrants from and after the first anniversary of the original issue date, another one-third of the warrants from and after the second anniversary of the original issue date and the final one-third may be converted from and after the third anniversary. Upon a change of control or in the event we exercise our redemption right with respect to the Preferred Units, all unvested warrants shall immediately vest and be exercisable in full. We received net proceeds of $235.0 million (net of offering costs of $5.0 million ) in connection with the issuance of Preferred Units and warrants. We allocated these net proceeds, on a relative fair value basis, to the Preferred Units ( $186.4 million ), which includes the value of the beneficial conversion feature, and warrants ( $48.6 million ). As discussed below, $131.5 million of the amount allocated to the Preferred Units is allocated to the intrinsic value of a beneficial conversion feature. A beneficial conversion feature is defined as a nondetachable conversion feature that is in the money at the commitment date. Per the applicable accounting guidance, we are required to allocate a portion of the proceeds allocated to the Preferred Units to the beneficial conversion feature based on the intrinsic value of the beneficial conversion feature. The intrinsic value is calculated at the commitment date based on the difference between the fair value of the common units at the issuance date (number of common units issuable at conversion multiplied by the per share value of our common units at the issuance date) and the proceeds attributed to the Preferred Units. We record the accretion attributed to the beneficial conversion feature as a deemed distribution using the effective interest method over the three year period prior to the effective dates of the holders’ conversion right. Accretion for the beneficial conversion feature was $2.2 million for the three months ended September 30, 2016 and $3.8 million for the six months ended September 30, 2016 . As discussed above, the Preferred Units are not mandatorily redeemable but are redeemable upon a change of control, which was not certain to occur at the issuance of the Preferred Units. Due to the redemption being conditioned upon an event that is not certain to occur or that is not under our control, we are required to record the value allocated to the Preferred Units, excluding the value of the beneficial conversion feature, between liabilities and equity (mezzanine or temporary equity) within our condensed consolidated balance sheet. The value allocated to the warrants and the beneficial conversion feature were recorded as part of Limited Partners’ equity within our condensed consolidated balance sheet. Amended and Restated Partnership Agreement On June 24, 2016, NGL Energy Holdings LLC executed the Third Amended and Restated Agreement of Limited Partnership. The preferences, rights, powers and duties of holders of the Preferred Units are defined in the amended and restated partnership agreement. The Preferred Units rank senior to the common units, with respect to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up. The Preferred Units have no stated maturity and are not subject to mandatory redemption or any sinking fund and will remain outstanding indefinitely unless redeemed by the Partnership or converted into common units at the election of the Partnership or the Preferred Unit holders or in connection with a change of control. At-The-Market Program On August 24, 2016, we entered into an equity distribution program in connection with an at-the-market program (the “ATM Program”) pursuant to which we may issue and sell common units for up to $200.0 million in gross proceeds. This ATM Program is registered with the SEC on an effective registration statement on Form S-3. During the three months ended September 30, 2016 , we sold 524,000 common units for proceeds of $9.6 million , net of offering costs of less than $0.1 million . In connection with the issuance of the common units, we issued 524 general partner units to our general partner and less than $0.1 million in order to maintain its 0.1% general partner interest in us. As of September 30, 2016 , approximately $190.4 million remained available for sale under the Partnership’s ATM Program. Subsequent to September 30, 2016, we sold an additional 192,000 common units for proceeds of $3.7 million , net of offering costs of less than $0.1 million . Equity-Based Incentive Compensation Our general partner has adopted a long-term incentive plan (“LTIP”), which allows for the issuance of equity-based compensation. Our general partner has granted certain restricted units to employees and directors, which vest in tranches, subject to the continued service of the recipients. The awards may also vest in the event of a change in control, at the discretion of the board of directors of our general partner. No distributions accrue to or are paid on the restricted units during the vesting period. The restricted units include awards that vest contingent on the continued service of the recipients through the vesting date (the “Service Awards”). The restricted units also include awards that are 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”). During the three months ended September 30, 2016, we changed our process for how taxes are withheld upon the vesting of restricted units. Previously, employees could choose to pay cash for their portion of the taxes or have us withhold enough units to meet their tax withholding requirements. Employees could also elect to have the units withheld to exceed the statutory minimums. Now, employees will still be able to pay cash to satisfy their tax obligation or they can elect to sell enough units, through a broker assisted cashless exercise program, to meet their tax obligation. As a result of this change in process, the unvested restricted units and future grants are eligible for equity classification. Prior to this change in process, we classified any Service Awards or Performance Awards granted as liabilities and were required to recalculate the fair value of the award at each reporting date. Awards classified as equity are valued only at their grant date and are not revalued at each reporting date. As of June 30, 2016, we had liabilities related to our Service Awards and Performance Awards of $25.6 million and $1.8 million , respectively, which we reclassified to equity. The following table summarizes the Service Award activity during the six months ended September 30, 2016 : Unvested Service Award units at March 31, 2016 2,297,132 Units granted 3,048,100 Units vested and issued (2,340,082 ) Units forfeited (322,100 ) Unvested Service Award units at September 30, 2016 2,683,050 The following table summarizes the scheduled vesting of our unvested Service Award units: Year Ending March 31, 2017 (six months) 10,000 2018 887,350 2019 894,800 Thereafter 890,900 Unvested Service Award units at September 30, 2016 2,683,050 Service Awards are valued at the market price as of the date of grant 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 must at least equal the portion of the grant-date value of the award that is vested at that date. During the three months ended September 30, 2016 and 2015 , we recorded compensation expense related to Service Award units of $25.8 million and $14.9 million , respectively. During the six months ended September 30, 2016 and 2015 , we recorded compensation expense related to Service Award units of $46.7 million and $33.4 million , respectively. Of the restricted units granted and vested during the six months ended September 30, 2016 , 1,008,091 units were granted as a bonus for performance during the fiscal year ended March 31, 2016. We accrued expense of $16.8 million during the fiscal year ended March 31, 2016 as an estimate of the value of such bonus units that would be granted. During the six months ended September 30, 2016 , we recorded an additional $2.2 million to true up the estimate to the $19.0 million of actual expense associated with these bonuses. Since the units were not formally granted until August 2016, the full $19.0 million is reflected in the expense during the three months and six months ended September 30, 2016 in the amounts in the preceding paragraph above. The following table summarizes the estimated future expense we expect to record on the unvested Service Award units at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 9,329 2018 12,239 2019 8,853 Thereafter 2,317 Total $ 32,738 During April 2015, our general partner granted Performance Award units to certain employees. The number of Performance Award units that will vest is contingent on the performance of our common units relative to the performance of the other entities in the Index. Performance will 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. As of September 30, 2016 , performance will be measured over the following periods: Vesting Date of Tranche Performance Period for Tranche July 1, 2017 July 1, 2014 through June 30, 2017 July 1, 2018 July 1, 2015 through June 30, 2018 July 1, 2019 July 1, 2016 through June 30, 2019 The following table summarizes the percentage of the maximum Performance Award units that will vest depending on the percentage of entities in the Index that NGL outperforms: Our Relative Total Unitholder Return Percentile Ranking Payout (% of Target Units) Less than 50th percentile 0% Between the 50th and 75th percentile 50%–100% Between the 75th and 90th percentile 100%–200% Above the 90% percentile 200% The following table summarizes the Performance Award activity during the six months ended September 30, 2016: Unvested Performance Award units at March 31, 2016 637,382 Units granted 932,309 Units forfeited (380,691 ) Unvested Performance Award units at September 30, 2016 1,189,000 During the July 1, 2013 through June 30, 2016 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 units vested on July 1, 2016 and are considered to be forfeited. We record the expense for each of the tranches of the Performance Awards on a straight-line basis over the period beginning with the grant date and ending with the vesting date of the tranche. During the three months ended September 30, 2016 and 2015, we recorded compensation expense related to Performance Award units of $1.6 million and $0.3 million , respectively. During the six months ended September 30, 2016 and 2015, we recorded compensation expense related to Performance Award units of $3.1 million and $18.1 million , respectively. The following table summarizes the estimated future expense we expect to record on the unvested Performance Award units at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 4,138 2018 6,197 2019 3,232 Thereafter 655 Total $ 14,222 The number of common units that may be delivered pursuant to awards under the LTIP is limited to 10% of the issued and outstanding common units. The maximum number of units deliverable under the LTIP plan automatically increases to 10% of the issued and outstanding common units immediately after each issuance of common units, unless the plan administrator determines to increase the maximum number of units deliverable by a lesser amount. Units withheld to satisfy tax withholding obligations are not considered to be delivered under the LTIP. In addition, when an award is forfeited, canceled, exercised, paid or otherwise terminates or expires without the delivery of units, the units subject to such award are again available for new awards under the LTIP. At September 30, 2016 , approximately 1.1 million common units remain available for issuance under the LTIP.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	6 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments Our cash and cash equivalents, accounts receivable, accounts payable, accrued expenses, and other current assets and liabilities (excluding derivative instruments) are carried at amounts which reasonably approximate their fair values due to their short-term nature. Commodity Derivatives The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported in our condensed consolidated balance sheet at the dates indicated: September 30, 2016 March 31, 2016 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 2,512 $ (40,260 ) $ 47,361 $ (3,983 ) Level 2 measurements 42,455 (32,253 ) 32,700 (28,612 ) 44,967 (72,513 ) 80,061 (32,595 ) Netting of counterparty contracts (1) (3,091 ) 3,091 (3,384 ) 3,384 Net cash collateral provided (held) 21 37,463 (18,176 ) 599 Commodity derivatives in condensed consolidated balance sheet $ 41,897 $ (31,959 ) $ 58,501 $ (28,612 ) (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. The following table summarizes the accounts that include our commodity derivative assets and liabilities in our condensed consolidated balance sheets at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Prepaid expenses and other current assets $ 41,897 $ 58,501 Accrued expenses and other payables (31,959 ) (28,612 ) Net commodity derivative asset $ 9,938 $ 29,889 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 September 30, 2016: Cross-commodity (1) October 2016–March 2017 126 $ 1,465 Crude oil fixed-price (2) October 2016–December 2016 (588 ) (3,041 ) Propane fixed-price (2) October 2016–December 2017 462 518 Refined products fixed-price (2) October 2016–September 2017 (5,628 ) (22,607 ) Other October 2016–March 2022 (3,881 ) (27,546 ) Net cash collateral provided 37,484 Net commodity derivative asset in condensed consolidated balance sheet $ 9,938 At March 31, 2016: Cross-commodity (1) April 2016–March 2017 251 $ 1,663 Crude oil fixed-price (2) April 2016–December 2016 (1,583 ) (3,655 ) Propane fixed-price (2) April 2016–December 2017 540 (592 ) Refined products fixed-price (2) April 2016–June 2017 (5,355 ) 48,557 Other April 2016–March 2017 1,493 47,466 Net cash collateral held (17,577 ) Net commodity derivative asset in condensed consolidated balance sheet $ 29,889 (1) We may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. These contracts are derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price. (2) 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. During the three months and six months ended September 30, 2016 , we recorded a net gain of $14.7 million and a net loss of $45.0 million , respectively, and during the three months and six months ended September 30, 2015 , we recorded net gains of $85.8 million and $44.5 million , respectively, from our commodity derivatives to cost of sales. 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 September 30, 2016 , 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 condensed consolidated balance sheets and recognized in our net income. Interest Rate Risk Our Revolving Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At September 30, 2016 , we had $2.0 billion of outstanding borrowings under our Revolving Credit Facility at an average interest rate of 2.83% . Fair Value of Fixed-Rate Notes The following table provides fair value estimates of our fixed-rate notes at September 30, 2016 (in thousands): 2019 Notes $ 360,459 2021 Notes 349,995 2022 Notes 253,838 For the 2019 Notes and the 2021 Notes, the fair value estimates were developed based on publicly traded quotes and would be classified as Level 1 in the fair value hierarchy. For the 2022 Notes, the fair value estimate was developed using observed yields on publicly traded notes issued by us, adjusted for differences in the key terms of those notes and the key terms of our notes (examples include differences in the tenor of the debt, credit standing of the issuer, whether the notes are publicly traded, and whether the notes are secured or unsecured). This fair value estimate would be classified as Level 3 in the fair value hierarchy.

Segments

Segments	6 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segments	Segments The following table summarizes certain financial data related to our segments for the periods indicated. 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. As Restated As Restated Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Revenues: Crude Oil Logistics: Crude oil sales $ 341,981 $ 997,106 $ 756,600 $ 2,309,889 Crude oil transportation and other 9,172 12,746 22,106 31,695 Elimination of intersegment sales (1,268 ) (2,274 ) (2,870 ) (6,222 ) Total Crude Oil Logistics revenues 349,885 1,007,578 775,836 2,335,362 Water Solutions: Service fees 28,528 35,203 54,225 71,941 Recovered hydrocarbons 5,681 10,746 12,877 26,564 Other revenues 5,524 1,545 8,384 3,282 Total Water Solutions revenues 39,733 47,494 75,486 101,787 Liquids: Propane sales 101,613 98,770 198,084 204,260 Other product sales 135,700 160,836 249,435 308,347 Other revenues 8,075 10,122 15,222 19,622 Elimination of intersegment sales (11,128 ) (10,736 ) (23,432 ) (24,252 ) Total Liquids revenues 234,260 258,992 439,309 507,977 Retail Propane: Propane sales 36,170 36,119 77,811 79,304 Distillate sales 5,589 7,678 16,044 20,625 Other revenues 9,331 9,409 17,638 17,724 Elimination of intersegment sales — — (16 ) — Total Retail Propane revenues 51,090 53,206 111,477 117,653 Refined Products and Renewables: Refined products sales 2,274,715 1,704,259 4,151,572 3,413,208 Renewables sales 95,830 93,189 202,312 199,342 Service fees (121 ) 28,739 11,145 56,812 Elimination of intersegment sales (102 ) (262 ) (144 ) (477 ) Total Refined Products and Renewables revenues 2,370,322 1,825,925 4,364,885 3,668,885 Corporate and Other 248 — 515 — Total revenues $ 3,045,538 $ 3,193,195 $ 5,767,508 $ 6,731,664 Depreciation and Amortization: Crude Oil Logistics $ 9,025 $ 10,053 $ 17,993 $ 20,055 Water Solutions 25,129 22,416 49,563 43,262 Liquids 4,425 2,745 8,874 7,749 Retail Propane 10,705 8,909 20,392 17,615 Refined Products and Renewables 416 11,152 833 25,327 Corporate and Other 903 1,486 1,854 2,584 Total depreciation and amortization $ 50,603 $ 56,761 $ 99,509 $ 116,592 Operating Income (Loss): Crude Oil Logistics $ (19,039 ) $ (75 ) $ (19,664 ) $ 11,885 Water Solutions (4,430 ) 18,257 75,034 28,704 Liquids 8,384 20,370 8,327 19,899 Retail Propane (8,717 ) (1,765 ) (11,219 ) (2,465 ) Refined Products and Renewables 11,387 (5,244 ) 161,156 27,776 Corporate and Other (23,413 ) (13,245 ) (55,562 ) (68,711 ) Total operating (loss) income $ (35,828 ) $ 18,298 $ 158,072 $ 17,088 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. Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Crude Oil Logistics $ 32,397 $ 44,384 $ 104,702 $ 107,023 Water Solutions 25,237 72,531 68,353 133,020 Liquids 6,693 18,886 13,161 36,064 Retail Propane 71,425 15,814 77,974 22,709 Refined Products and Renewables 1,143 7,588 1,167 23,283 Corporate and Other 614 — 1,732 1,169 Total $ 137,509 $ 159,203 $ 267,089 $ 323,268 The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Long-lived assets, net: Crude Oil Logistics $ 1,720,278 $ 1,679,027 Water Solutions 1,316,196 1,162,405 Liquids 575,963 572,081 Retail Propane 549,429 483,330 Refined Products and Renewables 219,157 180,783 Corporate and Other 32,495 36,198 Total $ 4,413,518 $ 4,113,824 Total assets: Crude Oil Logistics $ 2,318,083 $ 2,197,113 Water Solutions 1,354,786 1,236,875 Liquids 785,303 693,872 Retail Propane 611,340 538,267 Refined Products and Renewables 904,386 765,806 Corporate and Other 100,020 128,222 Total $ 6,073,918 $ 5,560,155

Transactions with Affiliates

Transactions with Affiliates	6 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Transactions with Affiliates	Transactions with Affiliates 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 condensed consolidated statements of operations. We also lease crude oil storage from SemGroup. We purchase ethanol from an equity method investee. These transactions are reported within cost of sales in our condensed consolidated statements of operations. Certain members of our management and members of their families as well as other associated parties own interests in entities from which we have purchased products and services and to which we have sold products and services. During the six months ended September 30, 2016 , $10.5 million of these transactions were capital expenditures and were recorded as increases to property, plant and equipment. The following table summarizes these related party transactions for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Sales to SemGroup $ 3,513 $ 4,593 $ 3,584 $ 42,031 Purchases from SemGroup 1,938 6,478 3,963 45,303 Sales to equity method investees 95 1,696 500 3,086 Purchases from equity method investees 27,345 24,816 57,992 55,764 Sales to entities affiliated with management 75 91 152 198 Purchases from entities affiliated with management 3,493 16,214 11,736 23,394 Accounts receivable from affiliates consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Receivables from SemGroup $ 3,401 $ 1,166 Receivables from equity method investees — 14,446 Receivables from entities affiliated with management 139 13 Total $ 3,540 $ 15,625 Accounts payable to affiliates consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Payables to SemGroup $ 4,015 $ 1,823 Payables to equity method investees 1,155 3,947 Payables to entities affiliated with management 1,074 1,423 Total $ 6,244 $ 7,193 We also have a loan receivable of $1.7 million at September 30, 2016 from an equity method investee with an initial maturity date of March 31, 2021, which can be extended for successive one -year periods unless one of the parties terminates the loan agreement. We had a loan receivable of $22.3 million at March 31, 2016 from an equity method investee. During the three months ended June 30, 2016, we received loan payments of $0.7 million from our investee in accordance with the loan agreement. During the three months ended June 30, 2016, we recorded an impairment of $1.7 million related to this loan receivable . On June 3, 2016, we acquired the remaining 65% ownership interest in this equity method investee (see Note 4 ) and this loan receivable is now eliminated upon consolidation.

Other Matters

Other Matters	6 Months Ended
	Sep. 30, 2016
Other Matters [Abstract]
Other Matters	Other Matters Purchase of Pipeline Capacity Allocations On certain interstate refined product pipelines, shipment demand exceeds available capacity, and capacity is allocated to shippers based on their historical shipment volumes. During the six months ended September 30, 2016 , we paid $42.0 million to acquire certain refined product pipeline capacity allocations from other shippers on the Colonial pipeline . Termination of Development Agreement On June 3, 2016, we entered into a purchase and sale agreement with the counterparty to the development agreement in our Water Solutions segment (as discussed in Note 4 ). Total cash consideration paid under the agreement was $49.6 million , of which $2.1 million was withheld and recorded in accrued expenses and other payables as of June 30, 2016, and in return we received the following: • Termination of the development agreement (see Note 4 ); • Additional interest in the water pipeline company we acquired in January 2016 (see Note 4 ); • Release of contingent consideration liabilities (see Note 4 ) attributed to certain of our water treatment and disposal facilities; • Certain parcels of land and permits to develop saltwater disposal wells and other parcels of land containing water wells and equipment; and • A two -year non-compete agreement with the counterparty. We accounted for the transaction as an acquisition of assets. Acquiring assets in groups requires not only ascertaining the cost of the asset (or net asset) group but also allocating that cost to the individual assets (or individual assets and liabilities) that make up the group. The cost of a group of assets acquired in an asset acquisition shall be allocated to the individual assets acquired or liabilities assumed/released based on their relative fair values and shall not give rise to goodwill or bargain purchase gains. We allocated $1.2 million of the total consideration to property, plant and equipment, $3.3 million to intangible assets, $2.8 million to noncontrolling interest, $25.5 million to the release of contingent consideration liabilities and $16.9 million to the termination of the development agreement. We recorded a $21.3 million gain on the release of $46.8 million of contingent consideration liabilities, which was recorded within gain on early extinguishment of liabilities in our condensed consolidated statement of operations during the six months ended September 30, 2016 . For the termination of the development agreement, we recorded a loss of $22.7 million , which included the carrying value of the development agreement asset that was written off (see Note 7 ). This loss was recorded within loss (gain) on disposal or impairment of assets, net in our condensed consolidated statement of operations during the six months ended September 30, 2016 .

Subsequent Events

Subsequent Events	6 Months Ended
	Sep. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events 2023 Notes In October 2016, we issued $700.0 million of Senior Unsecured Notes (the “2023 Notes”) in a private placement exempt from registration under the Securities Act of 1933, as amended (the “Securities Act”), pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of approximately $688.0 million , after the initial purchasers’ discount of $10.5 million and estimated offering costs of $1.5 million . We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility. The 2023 Notes mature on November 1, 2023 and bear interest at a fixed rate of 7.50% , payable on May 1 and November 1 of each year.

Condensed Consolidating Guarant

Condensed Consolidating Guarantor and Non-Guarantor Financial Information	6 Months Ended
	Sep. 30, 2016
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Condensed Consolidating Guarantor and Non-Guarantor Financial Information	Condensed Consolidating Guarantor and Non-Guarantor Financial Information Certain of our wholly owned subsidiaries have, jointly and severally, fully and unconditionally guaranteed the 2019 Notes and 2021 Notes (see Note 8 ). Pursuant to Rule 3-10 of Regulation S-X, we have presented in columnar format the condensed consolidating financial information for NGL Energy Partners LP (Parent), NGL Energy Finance Corp., the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis in the tables below. NGL Energy Partners LP and NGL Energy Finance Corp. are co-issuers of the 2019 Notes and 2021 Notes. Since NGL Energy Partners LP received the proceeds from the issuance of the 2019 Notes and 2021 Notes, all activity has been reflected in the NGL Energy Partners LP (Parent) column in the tables below. During the periods presented in the tables below, the status of certain subsidiaries changed, in that they either became guarantors of or ceased to be guarantors of the 2019 Notes and 2021 Notes. Such changes have been given retrospective application in the tables below. There are no significant restrictions that prevent the parent or any of the guarantor subsidiaries from obtaining funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries (other than the investments in non-guarantor subsidiaries) are restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act of 1933, as amended. For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to (from) consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating statement of cash flow tables below. Condensed Consolidating Balance Sheet (U.S. Dollars in Thousands) September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 10,116 $ — $ 12,179 $ 1,132 $ — $ 23,427 Accounts receivable-trade, net of allowance for doubtful accounts — — 585,720 6,354 — 592,074 Accounts receivable-affiliates — — 3,540 — — 3,540 Inventories — — 519,795 545 — 520,340 Prepaid expenses and other current assets — — 109,969 949 — 110,918 Total current assets 10,116 — 1,231,203 8,980 — 1,250,299 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,653,011 102,405 — 1,755,416 GOODWILL — — 1,448,661 19,294 — 1,467,955 INTANGIBLE ASSETS, net of accumulated amortization — — 1,166,439 23,708 — 1,190,147 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 190,662 — — 190,662 NET INTERCOMPANY RECEIVABLES (PAYABLES) 1,290,616 — (1,279,908 ) (10,708 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,689,633 — 96,577 — (1,786,210 ) — LOAN RECEIVABLE-AFFILIATE — — 1,700 — — 1,700 OTHER NONCURRENT ASSETS — — 217,618 121 — 217,739 Total assets $ 2,990,365 $ — $ 4,725,963 $ 143,800 $ (1,786,210 ) $ 6,073,918 LIABILITIES, CONVERTIBLE PREFERRED UNITS AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 510,535 $ 1,569 $ — $ 512,104 Accounts payable-affiliates 1 — 6,054 189 — 6,244 Accrued expenses and other payables 16,232 — 164,918 3,484 — 184,634 Advance payments received from customers — — 87,094 731 — 87,825 Current maturities of long-term debt — — 7,252 794 — 8,046 Total current liabilities 16,233 — 775,853 6,767 — 798,853 LONG-TERM DEBT, net of debt issuance costs and current maturities 989,171 — 2,067,264 6,573 — 3,063,008 OTHER NONCURRENT LIABILITIES — — 193,213 4,788 — 198,001 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 58,742 — — — — 58,742 EQUITY: Partners’ equity 1,926,219 — 1,690,096 125,851 (1,815,305 ) 1,926,861 Accumulated other comprehensive loss — — (463 ) (179 ) — (642 ) Noncontrolling interests — — — — 29,095 29,095 Total equity 1,926,219 — 1,689,633 125,672 (1,786,210 ) 1,955,314 Total liabilities, convertible preferred units and equity $ 2,990,365 $ — $ 4,725,963 $ 143,800 $ (1,786,210 ) $ 6,073,918 Condensed Consolidating Balance Sheet (U.S. Dollars in Thousands) March 31, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 25,749 $ — $ 784 $ 1,643 $ — $ 28,176 Accounts receivable-trade, net of allowance for doubtful accounts — — 516,362 4,652 — 521,014 Accounts receivable-affiliates — — 15,625 — — 15,625 Inventories — — 367,250 556 — 367,806 Prepaid expenses and other current assets — — 94,426 1,433 — 95,859 Total current assets 25,749 — 994,447 8,284 — 1,028,480 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,568,488 81,084 — 1,649,572 GOODWILL — — 1,313,364 1,998 — 1,315,362 INTANGIBLE ASSETS, net of accumulated amortization — — 1,146,355 2,535 — 1,148,890 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 219,550 — — 219,550 NET INTERCOMPANY RECEIVABLES (PAYABLES) 1,404,479 — (1,402,360 ) (2,119 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,254,383 — 42,227 — (1,296,610 ) — LOAN RECEIVABLE-AFFILIATE — — 22,262 — — 22,262 OTHER NONCURRENT ASSETS — — 175,512 527 — 176,039 Total assets $ 2,684,611 $ — $ 4,079,845 $ 92,309 $ (1,296,610 ) $ 5,560,155 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 417,707 $ 2,599 $ — $ 420,306 Accounts payable-affiliates 1 — 7,190 2 — 7,193 Accrued expenses and other payables 16,887 — 196,596 943 — 214,426 Advance payments received from customers — — 55,737 448 — 56,185 Current maturities of long-term debt — — 7,109 798 — 7,907 Total current liabilities 16,888 — 684,339 4,790 — 706,017 LONG-TERM DEBT, net of debt issuance costs and current maturities 1,011,365 — 1,894,428 7,044 — 2,912,837 OTHER NONCURRENT LIABILITIES — — 246,695 541 — 247,236 EQUITY: Partners’ equity 1,656,358 — 1,254,384 80,090 (1,334,317 ) 1,656,515 Accumulated other comprehensive loss — — (1 ) (156 ) — (157 ) Noncontrolling interests — — — — 37,707 37,707 Total equity 1,656,358 — 1,254,383 79,934 (1,296,610 ) 1,694,065 Total liabilities and equity $ 2,684,611 $ — $ 4,079,845 $ 92,309 $ (1,296,610 ) $ 5,560,155 Condensed Consolidating Statement of Operations (U.S. Dollars in Thousands) Three Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 3,034,053 $ 12,118 $ (633 ) $ 3,045,538 COST OF SALES — — 2,928,036 1,327 (633 ) 2,928,730 OPERATING COSTS AND EXPENSES: Operating — — 68,750 4,505 — 73,255 General and administrative — — 27,686 240 — 27,926 Depreciation and amortization — — 47,740 2,863 — 50,603 Loss (gain) on disposal or impairment of assets, net — — 896 (44 ) — 852 Operating (Loss) Income — — (39,055 ) 3,227 — (35,828 ) OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 53 — — 53 Interest expense (16,364 ) — (16,870 ) (291 ) 83 (33,442 ) Gain on early extinguishment of liabilities — — 938 — — 938 Other income, net — — 2,154 10 (83 ) 2,081 (Loss) Income Before Income Taxes (16,364 ) — (52,780 ) 2,946 — (66,198 ) INCOME TAX EXPENSE — — (460 ) — — (460 ) EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES (50,235 ) — 3,005 — 47,230 — Net (Loss) Income (66,599 ) — (50,235 ) 2,946 47,230 (66,658 ) LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS 59 59 LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS (8,668 ) (8,668 ) LESS: NET LOSS ALLOCATED TO GENERAL PARTNER 45 45 NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDE RS $ (66,599 ) $ — $ (50,235 ) $ 2,946 $ 38,666 $ (75,222 ) Condensed Consolidating Statement of Operations (U.S. Dollars in Thousands) As Restated Three Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 3,153,370 $ 49,442 $ (9,617 ) $ 3,193,195 COST OF SALES — — 3,009,777 5,610 (9,561 ) 3,005,826 OPERATING COSTS AND EXPENSES: Operating — — 75,023 22,663 (56 ) 97,630 General and administrative — — 24,538 4,760 — 29,298 Depreciation and amortization — — 45,006 11,755 — 56,761 Loss (gain) on disposal or impairment of assets, net — — 1,294 (3 ) — 1,291 Revaluation of liabilities — — (15,909 ) — — (15,909 ) Operating Income — — 13,641 4,657 — 18,298 OTHER INCOME (EXPENSE): Equity in (loss) earnings of unconsolidated entities — — (23 ) 2,455 — 2,432 Interest expense (17,913 ) — (11,351 ) (2,381 ) 74 (31,571 ) Other income, net — — 1,916 113 (74 ) 1,955 (Loss) Income Before Income Taxes (17,913 ) — 4,183 4,844 — (8,886 ) INCOME TAX BENEFIT (EXPENSE) — — 2,793 (7 ) — 2,786 EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES 8,316 — 1,340 — (9,656 ) — Net (Loss) Income (9,597 ) — 8,316 4,837 (9,656 ) (6,100 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (3,497 ) (3,497 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (16,185 ) (16,185 ) NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS $ (9,597 ) $ — $ 8,316 $ 4,837 $ (29,338 ) $ (25,782 ) Condensed Consolidating Statement of Operations (U.S. Dollars in Thousands) Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 5,749,034 $ 19,469 $ (995 ) $ 5,767,508 COST OF SALES — — 5,493,864 2,301 (995 ) 5,495,170 OPERATING COSTS AND EXPENSES: Operating — — 139,631 8,796 — 148,427 General and administrative — — 69,312 485 — 69,797 Depreciation and amortization — — 94,049 5,460 — 99,509 Gain on disposal or impairment of assets, net — — (203,443 ) (24 ) — (203,467 ) Operating Income — — 155,621 2,451 — 158,072 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 447 — — 447 Revaluation of investments — — (14,365 ) — — (14,365 ) Interest expense (32,690 ) — (30,898 ) (453 ) 161 (63,880 ) Gain on early extinguishment of liabilities 8,614 — 22,276 — — 30,890 Other income, net — — 5,990 24 (161 ) 5,853 (Loss) Income Before Income Taxes (24,076 ) — 139,071 2,022 — 117,017 INCOME TAX EXPENSE — — (922 ) — — (922 ) EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES 134,397 — (3,752 ) — (130,645 ) — Net Income 110,321 — 134,397 2,022 (130,645 ) 116,095 LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (5,774 ) (5,774 ) LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS (12,052 ) (12,052 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (158 ) (158 ) NET INCOME ALLOCATED TO COMMON UNITHOLDERS $ 110,321 $ — $ 134,397 $ 2,022 $ (148,629 ) $ 98,111 Condensed Consolidating Statement of Operations (U.S. Dollars in Thousands) As Restated Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 6,650,251 $ 100,621 $ (19,208 ) $ 6,731,664 COST OF SALES — — 6,333,438 14,022 (19,083 ) 6,328,377 OPERATING COSTS AND EXPENSES: Operating — — 160,323 43,022 (125 ) 203,220 General and administrative — — 81,208 10,571 — 91,779 Depreciation and amortization — — 90,545 26,047 — 116,592 Loss (gain) on disposal or impairment of assets, net — — 1,715 (3 ) — 1,712 Revaluation of liabilities — — (27,104 ) — — (27,104 ) Operating Income — — 10,126 6,962 — 17,088 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 2,872 8,278 — 11,150 Interest expense (35,714 ) — (22,344 ) (4,463 ) 148 (62,373 ) Other income, net — — 691 237 (148 ) 780 (Loss) Income Before Income Taxes (35,714 ) — (8,655 ) 11,014 — (33,355 ) INCOME TAX BENEFIT (EXPENSE) — — 2,286 (38 ) — 2,248 EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES (3,240 ) — 3,129 — 111 — Net (Loss) Income (38,954 ) — (3,240 ) 10,976 111 (31,107 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (7,847 ) (7,847 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (31,559 ) (31,559 ) NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS $ (38,954 ) $ — $ (3,240 ) $ 10,976 $ (39,295 ) $ (70,513 ) Condensed Consolidating Statements of Comprehensive Income (Loss) (U.S. Dollars in Thousands) Three Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (66,599 ) $ — $ (50,235 ) $ 2,946 $ 47,230 $ (66,658 ) Other comprehensive loss — — (333 ) — — (333 ) Comprehensive (loss) income $ (66,599 ) $ — $ (50,568 ) $ 2,946 $ 47,230 $ (66,991 ) As Restated Three Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (9,597 ) $ — $ 8,316 $ 4,837 $ (9,656 ) $ (6,100 ) Other comprehensive loss — — — (19 ) — (19 ) Comprehensive (loss) income $ (9,597 ) $ — $ 8,316 $ 4,818 $ (9,656 ) $ (6,119 ) Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income $ 110,321 $ — $ 134,397 $ 2,022 $ (130,645 ) $ 116,095 Other comprehensive loss — — (475 ) (10 ) — (485 ) Comprehensive income $ 110,321 $ — $ 133,922 $ 2,012 $ (130,645 ) $ 115,610 As Restated Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (38,954 ) $ — $ (3,240 ) $ 10,976 $ 111 $ (31,107 ) Other comprehensive loss — — — (27 ) — (27 ) Comprehensive (loss) income $ (38,954 ) $ — $ (3,240 ) $ 10,949 $ 111 $ (31,134 ) Condensed Consolidating Statement of Cash Flows (U.S. Dollars in Thousands) Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidated OPERATING ACTIVITIES: Net cash used in operating activities $ (31,541 ) $ — $ (12,751 ) $ (12,107 ) $ (56,399 ) INVESTING ACTIVITIES: Capital expenditures — — (158,333 ) (1,347 ) (159,680 ) Purchases of pipeline capacity allocations — — (41,953 ) — (41,953 ) Acquisitions of businesses, including acquired working capital, net of cash acquired — — (113,297 ) — (113,297 ) Cash flows from commodity derivatives — — (25,015 ) — (25,015 ) Proceeds from sales of assets — — 379 17 396 Proceeds from sale of TLP common units — — 112,370 — 112,370 Distributions of capital from unconsolidated entities — — 5,233 — 5,233 Payments on loan for natural gas liquids facility — — 4,324 — 4,324 Loan to affiliate — — (1,700 ) — (1,700 ) Payments on loan to affiliate — — 655 — 655 Payment to terminate development agreement — — (16,875 ) — (16,875 ) Net cash used in investing activities — — (234,212 ) (1,330 ) (235,542 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 770,000 — 770,000 Payments on revolving credit facilities — — (595,500 ) — (595,500 ) Repurchases of senior notes (15,129 ) — — — (15,129 ) Payments on other long-term debt — — (4,080 ) (343 ) (4,423 ) Debt issuance costs (255 ) — (65 ) — (320 ) Contributions from partners (442 ) — — — (442 ) Contributions from noncontrolling interest owners — — — 966 966 Distributions to partners (83,707 ) — — — (83,707 ) Distributions to noncontrolling interest owners — — — (2,750 ) (2,750 ) Proceeds from sale of convertible preferred units and warrants, net of offering costs 235,018 — — — 235,018 Proceeds from sale of common units, net of offering costs 9,383 — — — 9,383 Payments for the early extinguishment of liabilities — — (25,884 ) — (25,884 ) Net changes in advances with consolidated entities (128,960 ) — 113,907 15,053 — Other — — (20 ) — (20 ) Net cash provided by financing activities 15,908 — 258,358 12,926 287,192 Net (decrease) increase in cash and cash equivalents (15,633 ) — 11,395 (511 ) (4,749 ) Cash and cash equivalents, beginning of period 25,749 — 784 1,643 28,176 Cash and cash equivalents, end of period $ 10,116 $ — $ 12,179 $ 1,132 $ 23,427 Condensed Consolidating Statement of Cash Flows (U.S. Dollars in Thousands) Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities $ (34,469 ) $ — $ 173,058 $ 35,506 $ 174,095 INVESTING ACTIVITIES: Capital expenditures — — (184,680 ) (37,596 ) (222,276 ) Acquisitions of businesses, including acquired working capital, net of cash acquired — — (150,546 ) — (150,546 ) Cash flows from commodity derivatives — — 43,032 — 43,032 Proceeds from sales of assets — — 3,565 2 3,567 Investments in unconsolidated entities — — (2,700 ) (4,226 ) (6,926 ) Distributions of capital from unconsolidated entities — — 5,652 2,555 8,207 Loan for natural gas liquids facility — — (3,913 ) — (3,913 ) Payments on loan for natural gas liquids facility — — 3,546 — 3,546 Loan to affiliate — — (15,621 ) — (15,621 ) Net cash used in investing activities — — (301,665 ) (39,265 ) (340,930 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 1,311,500 43,200 1,354,700 Payments on revolving credit facilities — — (963,000 ) (43,600 ) (1,006,600 ) Payments on other long-term debt — — (2,274 ) (70 ) (2,344 ) Debt issuance costs 49 — (180 ) (1,249 ) (1,380 ) Contributions from partners 45 — — — 45 Contributions from noncontrolling interest owners — — — 6,613 6,613 Distributions to partners (154,824 ) — — — (154,824 ) Distributions to noncontrolling interest owners — — — (17,780 ) (17,780 ) Taxes paid on behalf of equity incentive plan participants — — (19,083 ) — (19,083 ) Common unit repurchases (3,650 ) — — — (3,650 ) Net changes in advances with consolidated entities 186,776 — (203,533 ) 16,757 — Other — — (33 ) (79 ) (112 ) Net cash provided by financing activities 28,396 — 123,397 3,792 155,585 Net (decrease) increase in cash and cash equivalents (6,073 ) — (5,210 ) 33 (11,250 ) Cash and cash equivalents, beginning of period 29,115 — 9,757 2,431 41,303 Cash and cash equivalents, end of period $ 23,042 $ — $ 4,547 $ 2,464 $ 30,053

Significant Accounting Polici25

Significant Accounting Policies (Policies)	6 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying unaudited condensed consolidated financial statements include our accounts and those of our controlled subsidiaries. Intercompany transactions and account balances have been eliminated in consolidation. Investments we cannot 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. We have included our proportionate share of assets, liabilities, and expenses related to this pipeline in our unaudited condensed consolidated financial statements. Our unaudited condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim consolidated financial information in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the unaudited condensed consolidated financial statements exclude certain information and notes required by GAAP for complete annual consolidated financial statements. However, we believe that the disclosures made are adequate to make the information presented not misleading. The unaudited condensed consolidated financial statements include all adjustments that we consider necessary for a fair presentation of our consolidated financial position and results of operations for the interim periods presented. Such adjustments consist only of normal recurring items, unless otherwise disclosed in this Quarterly Report. The unaudited condensed consolidated balance sheet at March 31, 2016 was derived from our audited consolidated financial statements for the fiscal year ended March 31, 2016 included in our Annual Report on Form 10-K (“Annual Report”). As previously reported, subsequent to the issuance of certain previously issued financial statements, in the fourth quarter of fiscal year 2016, we determined that there were errors in those financial statements from not recording certain contingent consideration liabilities related to royalty agreements assumed as part of acquisitions in our Water Solutions segment. The effect of the error was material to the financial statements for each of the first three quarters of the fiscal year ended March 31, 2016, so those quarters have been restated for the effects of the error correction. We have restated our previously issued condensed consolidated statements of operations and condensed consolidated statements of comprehensive loss for the three months and six months ended September 30, 2015 and condensed consolidated statement of cash flows for the six months ended September 30, 2015 . See Note 17 in our Annual Report for a summary of the impact of the error correction for the three months and six months ended September 30, 2015 . These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report. Due to the seasonal nature of certain of our operations and other factors, the results of operations for interim periods are not necessarily indicative of the results of operations to be expected for future periods or for the full fiscal year ending March 31, 2017 .
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 condensed consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations, 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 assets, the fair value of asset retirement obligations, the value of equity-based compensation, and accruals for various commitments and contingencies, among others. 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. 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 data (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 condensed consolidated balance sheets except for certain contracts that qualify for the normal purchase and normal sale election. Under this accounting policy election, we do not record the 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 commodity derivative instruments that do not qualify as normal purchases and normal sales (whether cash transactions or non-cash mark-to-market adjustments) are reported within cost of sales in our condensed 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. 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 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 risk 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.
Revenue Recognition	Revenue Recognition We record product sales revenues when title to the product transfers to the purchaser, which typically occurs when the purchaser receives the product. We record terminaling, transportation, storage, and service revenues when the service is performed, and we record tank and other rental revenues over the lease term. Revenues for our Water Solutions segment are recognized when we obtain the wastewater at our treatment and disposal facilities. 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 condensed consolidated statements of operations. We enter into certain contracts whereby we agree to purchase product from a counterparty and sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into at the same time and in contemplation of each other, we record the revenues for these transactions net of cost of sales.
Supplemental Cash Flow Information	Cash flows from settlements of commodity derivative instruments are included in investing activities in our condensed consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in operating activities in our condensed consolidated statements of cash flows.
Inventories	Inventories We value our inventories at the lower of cost or market, with cost determined using either the weighted-average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage. Market is determined based on estimated replacement cost using prices at the end of the reporting period. In performing this analysis, we consider fixed-price forward commitments and the opportunity to transfer propane inventory from our wholesale Liquids business to our Retail Propane business to sell the inventory in retail markets.
Investments in Unconsolidated Entities	Investments in Unconsolidated Entities Investments we cannot control, but can exercise significant influence over, are 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 condensed consolidated balance sheets; instead, our ownership interests are reported within investments in unconsolidated entities on our condensed 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 historical net book value of the net assets of the investee. We use the cumulative earnings approach to classify distributions received from unconsolidated entities as either operating activities or investing activities in our condensed consolidated statements of cash flows.
Noncontrolling Interests	Noncontrolling Interests We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our condensed consolidated financial statements represents the other owners’ interests in these entities.
Business Combination Measurement Period	Business Combination Measurement Period We record the assets acquired and liabilities assumed in a business combination at their acquisition date fair values. 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 value of the assets acquired and liabilities assumed in a business combination. As discussed in Note 4 , certain of our acquisitions are still within this measurement period, and as a result, the acquisition date fair values we have recorded for the assets acquired and liabilities assumed are subject to change. Also, as discussed in Note 4 , we made certain adjustments during the three months ended September 30, 2016 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the fiscal year ended March 31, 2016 . In September 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2015-16, “Simplifying the Accounting Adjustments for Measurement-Period Adjustments.” The ASU requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. This ASU requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. The ASU was effective for the Partnership beginning April 1, 2016, and required a prospective method of adoption.
Reclassifications	Reclassifications We have reclassified certain prior period financial statement information to be consistent with the classification methods used in the current fiscal year. These reclassifications did not impact previously reported amounts of equity, net income, or cash flows.
Recent Accounting Pronouncements	Recent Accounting Pronouncements 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. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectibility of the reported amount. The ASU is effective for the Partnership beginning April 1, 2020, and requires a modified retrospective method of adoption, although early adoption is permitted. We are in the process of assessing the impact of this ASU on our consolidated financial statements. In February 2016, the FASB issued ASU No. 2016-02, “Leases.” The ASU will replace previous lease accounting guidance in GAAP. The ASU requires the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. The ASU retains a distinction between finance leases and operating leases. The ASU is effective for the Partnership beginning April 1, 2019, and requires a modified retrospective method of adoption. We are in the process of assessing the impact of this ASU on our consolidated financial statements. In July 2015, the FASB issued ASU No. 2015-11, “Simplifying the Measurement of Inventory.” The ASU requires that inventory within the scope of the guidance be measured at the lower of cost or net realizable value. The ASU is effective for the Partnership beginning April 1, 2017, and requires a prospective method of adoption, although early adoption is permitted. We do not expect the adoption of this ASU to have a material impact on our consolidated financial position or results of operations. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers.” The ASU will replace most existing revenue recognition guidance in GAAP. The core principle of this ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU is effective for the Partnership beginning April 1, 2018, and allows for both full retrospective and modified retrospective methods of adoption. We are in the process of determining the method of adoption and assessing the impact of this ASU on our consolidated financial statements.

Significant Accounting Polici26

Significant Accounting Policies (Tables)	6 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Schedule of supplemental cash flow information	Non-cash investing and financing activities and supplemental disclosures of cash flow information are as follows for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) NON-CASH INVESTING AND FINANCING ACTIVITIES: Value of common units issued in business combinations $ 3,969 $ — $ 3,969 $ 11,367 SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION: Cash interest paid $ 29,711 $ 26,323 $ 58,869 $ 57,495 Income taxes paid (net of income tax refunds) 71 533 1,755 4,616
Schedule of inventories	Inventories consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Crude oil $ 86,495 $ 84,030 Natural gas liquids: Propane 73,704 28,639 Butane 44,929 8,461 Other 5,936 6,011 Refined products: Gasoline 126,821 80,569 Diesel 138,245 99,398 Renewables 34,328 52,458 Other 9,882 8,240 Total $ 520,340 $ 367,806
Schedule of investments in unconsolidated entities	Our investments in unconsolidated entities consist of the following at the dates indicated: Entity Segment Ownership Date Acquired September 30, 2016 March 31, 2016 (in thousands) Glass Mountain (1) Crude Oil Logistics 50% December 2013 $ 174,364 $ 179,594 Ethanol production facility Refined Products and Renewables 19% December 2013 13,507 12,570 Water treatment and disposal facility Water Solutions 50% August 2015 2,235 2,238 Retail propane company Retail Propane 50% April 2015 556 972 TLP (2) Refined Products and Renewables 0% July 2014 — 8,301 Water supply company (3) Water Solutions 100% June 2014 — 15,875 Total $ 190,662 $ 219,550 (1) When we acquired Gavilon, LLC, (“Gavilon Energy”), we recorded the investment in Glass Mountain Pipeline, LLC (“Glass Mountain”), which owns a crude oil pipeline in Oklahoma, at fair value. Our investment in Glass Mountain exceeds our proportionate share of the historical net book value of Glass Mountain’s net assets by $73.6 million at September 30, 2016 . This difference relates primarily to goodwill and customer relationships. (2) On April 1, 2016, we sold all of the TLP common units we owned. (3) On June 3, 2016, we acquired the remaining 65% ownership interest in the water supply company , and as a result, the water supply company is now consolidated in our condensed consolidated financial statements (see Note 4 ).
Schedule of other noncurrent assets	Other noncurrent assets consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Loan receivable (1) $ 44,957 $ 49,827 Tank bottoms (2) 42,044 42,044 Line fill (3) 35,013 35,060 Other 95,725 49,108 Total $ 217,739 $ 176,039 (1) Represents a loan receivable associated with our financing of the construction of a natural gas liquids facility to be utilized by a third party . (2) 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. At September 30, 2016 and March 31, 2016 , tank bottoms held in third party terminals consisted of 366,212 barrels and 366,212 barrels of refined products, respectively. Tank bottoms held in terminals we own are included within property, plant and equipment (see Note 5 ). (3) Represents minimum volumes of crude oil we are required to leave on certain third-party owned pipelines under long-term shipment commitments. At September 30, 2016 and March 31, 2016 , line fill consisted of 486,473 barrels and 487,104 barrels of crude oil, respectively.
Schedule of accrued expenses and other payables	Accrued expenses and other payables consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Accrued compensation and benefits $ 19,322 $ 40,517 Excise and other tax liabilities 56,147 59,455 Derivative liabilities 31,959 28,612 Accrued interest 19,594 20,543 Product exchange liabilities 7,045 5,843 Deferred gain on sale of general partner interest in TLP 30,113 30,113 Other 20,454 29,343 Total $ 184,634 $ 214,426

Income (Loss) Per Common Unit (

Income (Loss) Per Common Unit (Tables)	6 Months Ended
	Sep. 30, 2016
Earnings Per Unit [Abstract]
Schedule of income (loss) per common unit	Our income (loss) per common unit is as follows for the periods indicated: As Restated As Restated Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands, except unit and per unit amounts) Net (loss) income $ (66,658 ) $ (6,100 ) $ 116,095 $ (31,107 ) Less: Net loss (income) attributable to noncontrolling interests 59 (3,497 ) (5,774 ) (7,847 ) Net (loss) income attributable to NGL Energy Partners LP (66,599 ) (9,597 ) 110,321 (38,954 ) Less: Distributions to preferred unitholders (8,668 ) — (12,052 ) — Less: Net loss (income) allocated to general partner (1) 45 (16,185 ) (158 ) (31,559 ) Net (loss) income allocated to common unitholders $ (75,222 ) $ (25,782 ) $ 98,111 $ (70,513 ) Basic (loss) income per common unit $ (0.71 ) $ (0.25 ) $ 0.93 $ (0.67 ) Diluted (loss) income per common unit $ (0.71 ) $ (0.25 ) $ 0.91 $ (0.67 ) Basic weighted average common units outstanding 106,186,389 105,189,463 105,183,556 104,542,427 Diluted weighted average common units outstanding 106,186,389 105,189,463 107,997,549 104,542,427 (1) Net income (loss) allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are discussed in Note 11 .

Acquisitions (Tables)

Acquisitions (Tables)	6 Months Ended
	Sep. 30, 2016
Water Solutions Acquisitions 2017 Acquisitions
Business Acquisition [Line Items]
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed	The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Property, plant and equipment $ 15,021 Goodwill 18,933 Intangible assets 3,878 Current liabilities (1,239 ) Other noncurrent liabilities (9,697 ) Fair value of net assets acquired $ 26,896
Water supply company
Business Acquisition [Line Items]
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed	The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Current assets $ 1,713 Property, plant and equipment 8,874 Intangible asset 14,472 Current liabilities (2,765 ) Notes payable-intercompany (19,900 ) Fair value of net assets acquired $ 2,394
Retail propane 2017 acquisitions
Business Acquisition [Line Items]
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed	The following table summarizes the preliminary estimates of the fair values of the assets acquired and liabilities assumed (in thousands): Current assets $ 6,282 Property, plant and equipment 30,576 Goodwill 9,419 Intangible assets 36,950 Current liabilities (5,555 ) Other noncurrent liabilities (1,587 ) Fair value of net assets acquired $ 76,085

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Sep. 30, 2016
Property, Plant and Equipment [Abstract]
Schedule of property, plant and equipment	Our property, plant and equipment consists of the following at the dates indicated: Description Estimated September 30, 2016 March 31, 2016 (in thousands) Natural gas liquids terminal and storage assets 2–30 years $ 168,754 $ 169,758 Refined products terminal assets and equipment 20 years 6,844 6,844 Retail propane equipment 2–30 years 227,442 201,312 Vehicles and railcars 3–25 years 194,291 185,547 Water treatment facilities and equipment 3–30 years 535,255 508,239 Crude oil tanks and related equipment 2–40 years 140,245 137,894 Barges and towboats 5–40 years 89,973 86,731 Information technology equipment 3–7 years 42,218 38,653 Buildings and leasehold improvements 3–40 years 123,005 118,885 Land 50,132 47,114 Tank bottoms 20,105 20,355 Other 3–30 years 56,450 11,699 Construction in progress 425,066 383,032 2,079,780 1,916,063 Accumulated depreciation (324,364 ) (266,491 ) Net property, plant and equipment $ 1,755,416 $ 1,649,572
Schedule of depreciation expense and capitalized interest expense	The following table summarizes depreciation expense and capitalized interest expense for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Depreciation expense $ 28,703 $ 34,469 $ 56,357 $ 70,264 Capitalized interest expense 1,069 549 4,804 690
Summary of tank bottoms	The following table summarizes the tank bottoms included in the table above at the dates indicated: September 30, 2016 March 31, 2016 Product Volume Value Volume Value Crude oil 229 $ 19,120 231 $ 19,348 Other 24 985 24 1,007 Total $ 20,105 $ 20,355

Goodwill (Tables)

Goodwill (Tables)	6 Months Ended
	Sep. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of goodwill by segment, including changes to goodwill	The following table summarizes changes in goodwill by segment during the six months ended September 30, 2016 : Crude Oil Water Liquids Retail Refined Total (in thousands) Balances at March 31, 2016 $ 579,846 $ 290,915 $ 266,046 $ 127,428 $ 51,127 $ 1,315,362 Revisions to acquisition accounting (Note 4) — (419 ) — (2 ) — (421 ) Acquisitions (Note 4) — 18,933 — 9,419 — 28,352 Adjustment to initial impairment estimate — 124,662 — — — 124,662 Balances at September 30, 2016 $ 579,846 $ 434,091 $ 266,046 $ 136,845 $ 51,127 $ 1,467,955

Intangible Assets (Tables)

Intangible Assets (Tables)	6 Months Ended
	Sep. 30, 2016
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of intangible assets	Our intangible assets consist of the following at the dates indicated: September 30, 2016 March 31, 2016 Description Amortizable Lives Gross Carrying Accumulated Net Gross Carrying Accumulated Net (in thousands) Amortizable: Customer relationships 3–20 years $ 883,896 $ 274,111 $ 609,785 $ 852,118 $ 233,838 $ 618,280 Pipeline capacity rights 30 years 161,589 8,957 152,632 119,636 6,559 113,077 Water facility development agreement 5 years — — — 14,000 7,700 6,300 Executory contracts and other agreements 2–30 years 22,713 19,699 3,014 23,920 21,075 2,845 Non-compete agreements 2–32 years 31,784 15,101 16,683 20,903 13,564 7,339 Trade names 1–10 years 15,439 12,882 2,557 15,439 12,034 3,405 Debt issuance costs (1) 3 years 39,977 25,564 14,413 39,942 22,108 17,834 Total amortizable 1,155,398 356,314 799,084 1,085,958 316,878 769,080 Non-amortizable: Customer commitments 310,000 — 310,000 310,000 — 310,000 Rights-of-way and easements 47,721 — 47,721 47,190 — 47,190 Water rights 14,472 — 14,472 — — — Trade names 18,870 — 18,870 22,620 — 22,620 Total non-amortizable 391,063 — 391,063 379,810 — 379,810 Total $ 1,546,461 $ 356,314 $ 1,190,147 $ 1,465,768 $ 316,878 $ 1,148,890 (1) Includes debt issuance costs related to the Revolving Credit Facility (as defined herein). Debt issuance costs related to fixed-rate notes are reported as a reduction of the carrying amount of long-term debt.
Schedule of amortization expense	Amortization expense is as follows for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, Recorded In 2016 2015 2016 2015 (in thousands) Depreciation and amortization $ 21,900 $ 22,291 $ 43,152 $ 46,328 Cost of sales 1,749 1,700 3,345 3,401 Interest expense 1,731 1,470 3,456 2,954 Total $ 25,380 $ 25,461 $ 49,953 $ 52,683
Schedule of expected amortization of intangible assets	Expected amortization of intangible assets, exclusive of assets that are not yet amortizable, is as follows (in thousands): Year Ending March 31, 2017 (six months) $ 51,028 2018 98,717 2019 89,701 2020 82,185 2021 69,422 Thereafter 408,031 Total $ 799,084

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Schedule of long-term debt	Our long-term debt consists of the following at the dates indicated: September 30, 2016 March 31, 2016 Face Unamortized Book Face Unamortized Book (in thousands) Revolving credit facility: Expansion capital borrowings $ 1,312,000 $ — $ 1,312,000 $ 1,229,500 $ — $ 1,229,500 Working capital borrowings 710,500 — 710,500 618,500 — 618,500 5.125% Notes due 2019 383,467 (3,871 ) 379,596 388,467 (4,681 ) 383,786 6.875% Notes due 2021 369,063 (6,433 ) 362,630 388,289 (7,545 ) 380,744 6.650% Notes due 2022 250,000 (3,055 ) 246,945 250,000 (3,166 ) 246,834 Other long-term debt 59,506 (123 ) 59,383 61,488 (108 ) 61,380 3,084,536 (13,482 ) 3,071,054 2,936,244 (15,500 ) 2,920,744 Less: Current maturities 8,046 — 8,046 7,907 — 7,907 Long-term debt $ 3,076,490 $ (13,482 ) $ 3,063,008 $ 2,928,337 $ (15,500 ) $ 2,912,837 (1) Debt issuance costs related to the Revolving Credit Facility (as defined herein) are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt.
Schedule of future amortization expense of debt issuance costs	Expected amortization of debt issuance costs is as follows (in thousands): Year Ending March 31, 2017 (six months) $ 1,619 2018 3,229 2019 3,226 2020 2,236 2021 1,827 Thereafter 1,345 Total $ 13,482
Schedule of maturities of long-term debt	The scheduled maturities of our long-term debt are as follows at September 30, 2016 : Year Ending March 31, Revolving 2019 2021 2022 Other Total (in thousands) 2017 (six months) $ — $ — $ — $ — $ 3,405 $ 3,405 2018 — — — 25,000 8,014 33,014 2019 2,022,500 — — 50,000 6,857 2,079,357 2020 — 383,467 — 50,000 6,372 439,839 2021 — — — 50,000 34,728 84,728 Thereafter — — 369,063 75,000 130 444,193 Total $ 2,022,500 $ 383,467 $ 369,063 $ 250,000 $ 59,506 $ 3,084,536

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of change in asset retirement obligation	The following table is a rollforward of our asset retirement obligation, which is reported within other noncurrent liabilities in our condensed consolidated balance sheets (in thousands): Balance at March 31, 2016 $ 5,574 Liabilities assumed in acquisitions 406 Accretion expense 207 Balance at September 30, 2016 $ 6,187
Schedule of future minimum lease payments under contractual commitments	The following table summarizes future minimum lease payments under these agreements at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 67,837 2018 122,935 2019 101,047 2020 90,112 2021 80,457 Thereafter 135,486 Total $ 597,874
Schedule of future minimum throughput payments under agreements	The following table summarizes future minimum throughput payments under these agreements at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 26,008 2018 52,082 2019 52,170 2020 42,418 Total $ 172,678
Schedule of outstanding sales and purchase contracts	The following table summarizes such commitments at September 30, 2016 : Volume Value (in thousands) Purchase commitments: Natural gas liquids fixed-price (gallons) 35,592 $ 18,710 Natural gas liquids index-price (gallons) 587,044 347,020 Crude oil fixed-price (barrels) 1,993 88,079 Crude oil index-price (barrels) 14,466 655,273 Sale commitments: Natural gas liquids fixed-price (gallons) 163,546 105,868 Natural gas liquids index-price (gallons) 414,042 317,983 Crude oil fixed-price (barrels) 3,415 152,584 Crude oil index-price (barrels) 12,953 637,731

Equity (Tables)

Equity (Tables)	6 Months Ended
	Sep. 30, 2016
Equity
Schedule of dividends declared	The following table summarizes distributions declared for the last three quarters: Date Declared Record Date Date Paid/Payable Amount Per Unit Amount Paid/Payable to Limited Partners Amount Paid/Payable to General Partner (in thousands) (in thousands) April 21, 2016 May 3, 2016 May 13, 2016 $ 0.3900 $ 40,626 $ 70 July 22, 2016 August 4, 2016 August 12, 2016 0.3900 41,146 71 October 20, 2016 November 4, 2016 November 14, 2016 0.3900 41,907 72
Service awards
Equity
Schedule of service awards activity	The following table summarizes the Service Award activity during the six months ended September 30, 2016 : Unvested Service Award units at March 31, 2016 2,297,132 Units granted 3,048,100 Units vested and issued (2,340,082 ) Units forfeited (322,100 ) Unvested Service Award units at September 30, 2016 2,683,050
Summary of scheduled vesting of awards	The following table summarizes the scheduled vesting of our unvested Service Award units: Year Ending March 31, 2017 (six months) 10,000 2018 887,350 2019 894,800 Thereafter 890,900 Unvested Service Award units at September 30, 2016 2,683,050
Schedule of estimated equity-based expense to be recorded on the awards granted	The following table summarizes the estimated future expense we expect to record on the unvested Service Award units at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 9,329 2018 12,239 2019 8,853 Thereafter 2,317 Total $ 32,738
Performance awards
Equity
Schedule of service awards activity	The following table summarizes the Performance Award activity during the six months ended September 30, 2016: Unvested Performance Award units at March 31, 2016 637,382 Units granted 932,309 Units forfeited (380,691 ) Unvested Performance Award units at September 30, 2016 1,189,000
Schedule of estimated equity-based expense to be recorded on the awards granted	The following table summarizes the estimated future expense we expect to record on the unvested Performance Award units at September 30, 2016 (in thousands): Year Ending March 31, 2017 (six months) $ 4,138 2018 6,197 2019 3,232 Thereafter 655 Total $ 14,222
Schedule of performance measurement period for each tranche	As of September 30, 2016 , performance will be measured over the following periods: Vesting Date of Tranche Performance Period for Tranche July 1, 2017 July 1, 2014 through June 30, 2017 July 1, 2018 July 1, 2015 through June 30, 2018 July 1, 2019 July 1, 2016 through June 30, 2019
Summary of percentage of the maximum performance award units that will vest depending on the percentage of entities in the Index that NGL outperforms	The following table summarizes the percentage of the maximum Performance Award units that will vest depending on the percentage of entities in the Index that NGL outperforms: Our Relative Total Unitholder Return Percentile Ranking Payout (% of Target Units) Less than 50th percentile 0% Between the 50th and 75th percentile 50%–100% Between the 75th and 90th percentile 100%–200% Above the 90% percentile 200%

Fair Value of Financial Instr35

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Sep. 30, 2016
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 condensed consolidated balance sheet at the dates indicated: September 30, 2016 March 31, 2016 Derivative Derivative Derivative Derivative (in thousands) Level 1 measurements $ 2,512 $ (40,260 ) $ 47,361 $ (3,983 ) Level 2 measurements 42,455 (32,253 ) 32,700 (28,612 ) 44,967 (72,513 ) 80,061 (32,595 ) Netting of counterparty contracts (1) (3,091 ) 3,091 (3,384 ) 3,384 Net cash collateral provided (held) 21 37,463 (18,176 ) 599 Commodity derivatives in condensed consolidated balance sheet $ 41,897 $ (31,959 ) $ 58,501 $ (28,612 ) (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.
Schedule of location of commodity derivative assets and liabilities reported on the condensed consolidated balance sheets	The following table summarizes the accounts that include our commodity derivative assets and liabilities in our condensed consolidated balance sheets at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Prepaid expenses and other current assets $ 41,897 $ 58,501 Accrued expenses and other payables (31,959 ) (28,612 ) Net commodity derivative asset $ 9,938 $ 29,889
Summary 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 September 30, 2016: Cross-commodity (1) October 2016–March 2017 126 $ 1,465 Crude oil fixed-price (2) October 2016–December 2016 (588 ) (3,041 ) Propane fixed-price (2) October 2016–December 2017 462 518 Refined products fixed-price (2) October 2016–September 2017 (5,628 ) (22,607 ) Other October 2016–March 2022 (3,881 ) (27,546 ) Net cash collateral provided 37,484 Net commodity derivative asset in condensed consolidated balance sheet $ 9,938 At March 31, 2016: Cross-commodity (1) April 2016–March 2017 251 $ 1,663 Crude oil fixed-price (2) April 2016–December 2016 (1,583 ) (3,655 ) Propane fixed-price (2) April 2016–December 2017 540 (592 ) Refined products fixed-price (2) April 2016–June 2017 (5,355 ) 48,557 Other April 2016–March 2017 1,493 47,466 Net cash collateral held (17,577 ) Net commodity derivative asset in condensed consolidated balance sheet $ 29,889 (1) We may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. These contracts are derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price. (2) 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.
Schedule of fair value estimates of fixed-rate notes	The following table provides fair value estimates of our fixed-rate notes at September 30, 2016 (in thousands): 2019 Notes $ 360,459 2021 Notes 349,995 2022 Notes 253,838

Segments (Tables)

Segments (Tables)	6 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Schedule of certain information related to results of operations by segment	As Restated As Restated Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Revenues: Crude Oil Logistics: Crude oil sales $ 341,981 $ 997,106 $ 756,600 $ 2,309,889 Crude oil transportation and other 9,172 12,746 22,106 31,695 Elimination of intersegment sales (1,268 ) (2,274 ) (2,870 ) (6,222 ) Total Crude Oil Logistics revenues 349,885 1,007,578 775,836 2,335,362 Water Solutions: Service fees 28,528 35,203 54,225 71,941 Recovered hydrocarbons 5,681 10,746 12,877 26,564 Other revenues 5,524 1,545 8,384 3,282 Total Water Solutions revenues 39,733 47,494 75,486 101,787 Liquids: Propane sales 101,613 98,770 198,084 204,260 Other product sales 135,700 160,836 249,435 308,347 Other revenues 8,075 10,122 15,222 19,622 Elimination of intersegment sales (11,128 ) (10,736 ) (23,432 ) (24,252 ) Total Liquids revenues 234,260 258,992 439,309 507,977 Retail Propane: Propane sales 36,170 36,119 77,811 79,304 Distillate sales 5,589 7,678 16,044 20,625 Other revenues 9,331 9,409 17,638 17,724 Elimination of intersegment sales — — (16 ) — Total Retail Propane revenues 51,090 53,206 111,477 117,653 Refined Products and Renewables: Refined products sales 2,274,715 1,704,259 4,151,572 3,413,208 Renewables sales 95,830 93,189 202,312 199,342 Service fees (121 ) 28,739 11,145 56,812 Elimination of intersegment sales (102 ) (262 ) (144 ) (477 ) Total Refined Products and Renewables revenues 2,370,322 1,825,925 4,364,885 3,668,885 Corporate and Other 248 — 515 — Total revenues $ 3,045,538 $ 3,193,195 $ 5,767,508 $ 6,731,664 Depreciation and Amortization: Crude Oil Logistics $ 9,025 $ 10,053 $ 17,993 $ 20,055 Water Solutions 25,129 22,416 49,563 43,262 Liquids 4,425 2,745 8,874 7,749 Retail Propane 10,705 8,909 20,392 17,615 Refined Products and Renewables 416 11,152 833 25,327 Corporate and Other 903 1,486 1,854 2,584 Total depreciation and amortization $ 50,603 $ 56,761 $ 99,509 $ 116,592 Operating Income (Loss): Crude Oil Logistics $ (19,039 ) $ (75 ) $ (19,664 ) $ 11,885 Water Solutions (4,430 ) 18,257 75,034 28,704 Liquids 8,384 20,370 8,327 19,899 Retail Propane (8,717 ) (1,765 ) (11,219 ) (2,465 ) Refined Products and Renewables 11,387 (5,244 ) 161,156 27,776 Corporate and Other (23,413 ) (13,245 ) (55,562 ) (68,711 ) Total operating (loss) income $ (35,828 ) $ 18,298 $ 158,072 $ 17,088
Schedule of additions to property, plant and equipment 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. Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Crude Oil Logistics $ 32,397 $ 44,384 $ 104,702 $ 107,023 Water Solutions 25,237 72,531 68,353 133,020 Liquids 6,693 18,886 13,161 36,064 Retail Propane 71,425 15,814 77,974 22,709 Refined Products and Renewables 1,143 7,588 1,167 23,283 Corporate and Other 614 — 1,732 1,169 Total $ 137,509 $ 159,203 $ 267,089 $ 323,268
Schedule of long-lived assets (consisting of property, plant and equipment, intangible assets and goodwill) and total assets by segment	The following tables summarize long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Long-lived assets, net: Crude Oil Logistics $ 1,720,278 $ 1,679,027 Water Solutions 1,316,196 1,162,405 Liquids 575,963 572,081 Retail Propane 549,429 483,330 Refined Products and Renewables 219,157 180,783 Corporate and Other 32,495 36,198 Total $ 4,413,518 $ 4,113,824 Total assets: Crude Oil Logistics $ 2,318,083 $ 2,197,113 Water Solutions 1,354,786 1,236,875 Liquids 785,303 693,872 Retail Propane 611,340 538,267 Refined Products and Renewables 904,386 765,806 Corporate and Other 100,020 128,222 Total $ 6,073,918 $ 5,560,155

Transactions with Affiliates (T

Transactions with Affiliates (Tables)	6 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Summary of purchase and sales transactions of products and services	The following table summarizes these related party transactions for the periods indicated: Three Months Ended September 30, Six Months Ended September 30, 2016 2015 2016 2015 (in thousands) Sales to SemGroup $ 3,513 $ 4,593 $ 3,584 $ 42,031 Purchases from SemGroup 1,938 6,478 3,963 45,303 Sales to equity method investees 95 1,696 500 3,086 Purchases from equity method investees 27,345 24,816 57,992 55,764 Sales to entities affiliated with management 75 91 152 198 Purchases from entities affiliated with management 3,493 16,214 11,736 23,394
Schedule of accounts receivable from affiliates	Accounts receivable from affiliates consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Receivables from SemGroup $ 3,401 $ 1,166 Receivables from equity method investees — 14,446 Receivables from entities affiliated with management 139 13 Total $ 3,540 $ 15,625
Schedule of accounts payable to affiliates	Accounts payable to affiliates consist of the following at the dates indicated: September 30, 2016 March 31, 2016 (in thousands) Payables to SemGroup $ 4,015 $ 1,823 Payables to equity method investees 1,155 3,947 Payables to entities affiliated with management 1,074 1,423 Total $ 6,244 $ 7,193

Condensed Consolidating Guara38

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Tables)	6 Months Ended
	Sep. 30, 2016
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Schedule of Condensed Consolidating Balance Sheets	March 31, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 25,749 $ — $ 784 $ 1,643 $ — $ 28,176 Accounts receivable-trade, net of allowance for doubtful accounts — — 516,362 4,652 — 521,014 Accounts receivable-affiliates — — 15,625 — — 15,625 Inventories — — 367,250 556 — 367,806 Prepaid expenses and other current assets — — 94,426 1,433 — 95,859 Total current assets 25,749 — 994,447 8,284 — 1,028,480 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,568,488 81,084 — 1,649,572 GOODWILL — — 1,313,364 1,998 — 1,315,362 INTANGIBLE ASSETS, net of accumulated amortization — — 1,146,355 2,535 — 1,148,890 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 219,550 — — 219,550 NET INTERCOMPANY RECEIVABLES (PAYABLES) 1,404,479 — (1,402,360 ) (2,119 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,254,383 — 42,227 — (1,296,610 ) — LOAN RECEIVABLE-AFFILIATE — — 22,262 — — 22,262 OTHER NONCURRENT ASSETS — — 175,512 527 — 176,039 Total assets $ 2,684,611 $ — $ 4,079,845 $ 92,309 $ (1,296,610 ) $ 5,560,155 LIABILITIES AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 417,707 $ 2,599 $ — $ 420,306 Accounts payable-affiliates 1 — 7,190 2 — 7,193 Accrued expenses and other payables 16,887 — 196,596 943 — 214,426 Advance payments received from customers — — 55,737 448 — 56,185 Current maturities of long-term debt — — 7,109 798 — 7,907 Total current liabilities 16,888 — 684,339 4,790 — 706,017 LONG-TERM DEBT, net of debt issuance costs and current maturities 1,011,365 — 1,894,428 7,044 — 2,912,837 OTHER NONCURRENT LIABILITIES — — 246,695 541 — 247,236 EQUITY: Partners’ equity 1,656,358 — 1,254,384 80,090 (1,334,317 ) 1,656,515 Accumulated other comprehensive loss — — (1 ) (156 ) — (157 ) Noncontrolling interests — — — — 37,707 37,707 Total equity 1,656,358 — 1,254,383 79,934 (1,296,610 ) 1,694,065 Total liabilities and equity $ 2,684,611 $ — $ 4,079,845 $ 92,309 $ (1,296,610 ) $ 5,560,155 September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated ASSETS CURRENT ASSETS: Cash and cash equivalents $ 10,116 $ — $ 12,179 $ 1,132 $ — $ 23,427 Accounts receivable-trade, net of allowance for doubtful accounts — — 585,720 6,354 — 592,074 Accounts receivable-affiliates — — 3,540 — — 3,540 Inventories — — 519,795 545 — 520,340 Prepaid expenses and other current assets — — 109,969 949 — 110,918 Total current assets 10,116 — 1,231,203 8,980 — 1,250,299 PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation — — 1,653,011 102,405 — 1,755,416 GOODWILL — — 1,448,661 19,294 — 1,467,955 INTANGIBLE ASSETS, net of accumulated amortization — — 1,166,439 23,708 — 1,190,147 INVESTMENTS IN UNCONSOLIDATED ENTITIES — — 190,662 — — 190,662 NET INTERCOMPANY RECEIVABLES (PAYABLES) 1,290,616 — (1,279,908 ) (10,708 ) — — INVESTMENTS IN CONSOLIDATED SUBSIDIARIES 1,689,633 — 96,577 — (1,786,210 ) — LOAN RECEIVABLE-AFFILIATE — — 1,700 — — 1,700 OTHER NONCURRENT ASSETS — — 217,618 121 — 217,739 Total assets $ 2,990,365 $ — $ 4,725,963 $ 143,800 $ (1,786,210 ) $ 6,073,918 LIABILITIES, CONVERTIBLE PREFERRED UNITS AND EQUITY CURRENT LIABILITIES: Accounts payable-trade $ — $ — $ 510,535 $ 1,569 $ — $ 512,104 Accounts payable-affiliates 1 — 6,054 189 — 6,244 Accrued expenses and other payables 16,232 — 164,918 3,484 — 184,634 Advance payments received from customers — — 87,094 731 — 87,825 Current maturities of long-term debt — — 7,252 794 — 8,046 Total current liabilities 16,233 — 775,853 6,767 — 798,853 LONG-TERM DEBT, net of debt issuance costs and current maturities 989,171 — 2,067,264 6,573 — 3,063,008 OTHER NONCURRENT LIABILITIES — — 193,213 4,788 — 198,001 CLASS A 10.75% CONVERTIBLE PREFERRED UNITS 58,742 — — — — 58,742 EQUITY: Partners’ equity 1,926,219 — 1,690,096 125,851 (1,815,305 ) 1,926,861 Accumulated other comprehensive loss — — (463 ) (179 ) — (642 ) Noncontrolling interests — — — — 29,095 29,095 Total equity 1,926,219 — 1,689,633 125,672 (1,786,210 ) 1,955,314 Total liabilities, convertible preferred units and equity $ 2,990,365 $ — $ 4,725,963 $ 143,800 $ (1,786,210 ) $ 6,073,918
Schedule of Condensed Consolidating Statements of Operations	Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 5,749,034 $ 19,469 $ (995 ) $ 5,767,508 COST OF SALES — — 5,493,864 2,301 (995 ) 5,495,170 OPERATING COSTS AND EXPENSES: Operating — — 139,631 8,796 — 148,427 General and administrative — — 69,312 485 — 69,797 Depreciation and amortization — — 94,049 5,460 — 99,509 Gain on disposal or impairment of assets, net — — (203,443 ) (24 ) — (203,467 ) Operating Income — — 155,621 2,451 — 158,072 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 447 — — 447 Revaluation of investments — — (14,365 ) — — (14,365 ) Interest expense (32,690 ) — (30,898 ) (453 ) 161 (63,880 ) Gain on early extinguishment of liabilities 8,614 — 22,276 — — 30,890 Other income, net — — 5,990 24 (161 ) 5,853 (Loss) Income Before Income Taxes (24,076 ) — 139,071 2,022 — 117,017 INCOME TAX EXPENSE — — (922 ) — — (922 ) EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES 134,397 — (3,752 ) — (130,645 ) — Net Income 110,321 — 134,397 2,022 (130,645 ) 116,095 LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (5,774 ) (5,774 ) LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS (12,052 ) (12,052 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (158 ) (158 ) NET INCOME ALLOCATED TO COMMON UNITHOLDERS $ 110,321 $ — $ 134,397 $ 2,022 $ (148,629 ) $ 98,111 Three Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 3,034,053 $ 12,118 $ (633 ) $ 3,045,538 COST OF SALES — — 2,928,036 1,327 (633 ) 2,928,730 OPERATING COSTS AND EXPENSES: Operating — — 68,750 4,505 — 73,255 General and administrative — — 27,686 240 — 27,926 Depreciation and amortization — — 47,740 2,863 — 50,603 Loss (gain) on disposal or impairment of assets, net — — 896 (44 ) — 852 Operating (Loss) Income — — (39,055 ) 3,227 — (35,828 ) OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 53 — — 53 Interest expense (16,364 ) — (16,870 ) (291 ) 83 (33,442 ) Gain on early extinguishment of liabilities — — 938 — — 938 Other income, net — — 2,154 10 (83 ) 2,081 (Loss) Income Before Income Taxes (16,364 ) — (52,780 ) 2,946 — (66,198 ) INCOME TAX EXPENSE — — (460 ) — — (460 ) EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES (50,235 ) — 3,005 — 47,230 — Net (Loss) Income (66,599 ) — (50,235 ) 2,946 47,230 (66,658 ) LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS 59 59 LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS (8,668 ) (8,668 ) LESS: NET LOSS ALLOCATED TO GENERAL PARTNER 45 45 NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDE RS $ (66,599 ) $ — $ (50,235 ) $ 2,946 $ 38,666 $ (75,222 ) As Restated Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 6,650,251 $ 100,621 $ (19,208 ) $ 6,731,664 COST OF SALES — — 6,333,438 14,022 (19,083 ) 6,328,377 OPERATING COSTS AND EXPENSES: Operating — — 160,323 43,022 (125 ) 203,220 General and administrative — — 81,208 10,571 — 91,779 Depreciation and amortization — — 90,545 26,047 — 116,592 Loss (gain) on disposal or impairment of assets, net — — 1,715 (3 ) — 1,712 Revaluation of liabilities — — (27,104 ) — — (27,104 ) Operating Income — — 10,126 6,962 — 17,088 OTHER INCOME (EXPENSE): Equity in earnings of unconsolidated entities — — 2,872 8,278 — 11,150 Interest expense (35,714 ) — (22,344 ) (4,463 ) 148 (62,373 ) Other income, net — — 691 237 (148 ) 780 (Loss) Income Before Income Taxes (35,714 ) — (8,655 ) 11,014 — (33,355 ) INCOME TAX BENEFIT (EXPENSE) — — 2,286 (38 ) — 2,248 EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES (3,240 ) — 3,129 — 111 — Net (Loss) Income (38,954 ) — (3,240 ) 10,976 111 (31,107 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (7,847 ) (7,847 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (31,559 ) (31,559 ) NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS $ (38,954 ) $ — $ (3,240 ) $ 10,976 $ (39,295 ) $ (70,513 ) As Restated Three Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated REVENUES $ — $ — $ 3,153,370 $ 49,442 $ (9,617 ) $ 3,193,195 COST OF SALES — — 3,009,777 5,610 (9,561 ) 3,005,826 OPERATING COSTS AND EXPENSES: Operating — — 75,023 22,663 (56 ) 97,630 General and administrative — — 24,538 4,760 — 29,298 Depreciation and amortization — — 45,006 11,755 — 56,761 Loss (gain) on disposal or impairment of assets, net — — 1,294 (3 ) — 1,291 Revaluation of liabilities — — (15,909 ) — — (15,909 ) Operating Income — — 13,641 4,657 — 18,298 OTHER INCOME (EXPENSE): Equity in (loss) earnings of unconsolidated entities — — (23 ) 2,455 — 2,432 Interest expense (17,913 ) — (11,351 ) (2,381 ) 74 (31,571 ) Other income, net — — 1,916 113 (74 ) 1,955 (Loss) Income Before Income Taxes (17,913 ) — 4,183 4,844 — (8,886 ) INCOME TAX BENEFIT (EXPENSE) — — 2,793 (7 ) — 2,786 EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES 8,316 — 1,340 — (9,656 ) — Net (Loss) Income (9,597 ) — 8,316 4,837 (9,656 ) (6,100 ) LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (3,497 ) (3,497 ) LESS: NET INCOME ALLOCATED TO GENERAL PARTNER (16,185 ) (16,185 ) NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS $ (9,597 ) $ — $ 8,316 $ 4,837 $ (29,338 ) $ (25,782 )
Schedule of Condensed Consolidating Statements of Comprehensive Income (Loss)	Three Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (66,599 ) $ — $ (50,235 ) $ 2,946 $ 47,230 $ (66,658 ) Other comprehensive loss — — (333 ) — — (333 ) Comprehensive (loss) income $ (66,599 ) $ — $ (50,568 ) $ 2,946 $ 47,230 $ (66,991 ) As Restated Three Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (9,597 ) $ — $ 8,316 $ 4,837 $ (9,656 ) $ (6,100 ) Other comprehensive loss — — — (19 ) — (19 ) Comprehensive (loss) income $ (9,597 ) $ — $ 8,316 $ 4,818 $ (9,656 ) $ (6,119 ) Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net income $ 110,321 $ — $ 134,397 $ 2,022 $ (130,645 ) $ 116,095 Other comprehensive loss — — (475 ) (10 ) — (485 ) Comprehensive income $ 110,321 $ — $ 133,922 $ 2,012 $ (130,645 ) $ 115,610 As Restated Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidating Consolidated Net (loss) income $ (38,954 ) $ — $ (3,240 ) $ 10,976 $ 111 $ (31,107 ) Other comprehensive loss — — — (27 ) — (27 ) Comprehensive (loss) income $ (38,954 ) $ — $ (3,240 ) $ 10,949 $ 111 $ (31,134 )
Schedule of Condensed Consolidating Statements of Cash Flows	Six Months Ended September 30, 2015 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidated OPERATING ACTIVITIES: Net cash (used in) provided by operating activities $ (34,469 ) $ — $ 173,058 $ 35,506 $ 174,095 INVESTING ACTIVITIES: Capital expenditures — — (184,680 ) (37,596 ) (222,276 ) Acquisitions of businesses, including acquired working capital, net of cash acquired — — (150,546 ) — (150,546 ) Cash flows from commodity derivatives — — 43,032 — 43,032 Proceeds from sales of assets — — 3,565 2 3,567 Investments in unconsolidated entities — — (2,700 ) (4,226 ) (6,926 ) Distributions of capital from unconsolidated entities — — 5,652 2,555 8,207 Loan for natural gas liquids facility — — (3,913 ) — (3,913 ) Payments on loan for natural gas liquids facility — — 3,546 — 3,546 Loan to affiliate — — (15,621 ) — (15,621 ) Net cash used in investing activities — — (301,665 ) (39,265 ) (340,930 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 1,311,500 43,200 1,354,700 Payments on revolving credit facilities — — (963,000 ) (43,600 ) (1,006,600 ) Payments on other long-term debt — — (2,274 ) (70 ) (2,344 ) Debt issuance costs 49 — (180 ) (1,249 ) (1,380 ) Contributions from partners 45 — — — 45 Contributions from noncontrolling interest owners — — — 6,613 6,613 Distributions to partners (154,824 ) — — — (154,824 ) Distributions to noncontrolling interest owners — — — (17,780 ) (17,780 ) Taxes paid on behalf of equity incentive plan participants — — (19,083 ) — (19,083 ) Common unit repurchases (3,650 ) — — — (3,650 ) Net changes in advances with consolidated entities 186,776 — (203,533 ) 16,757 — Other — — (33 ) (79 ) (112 ) Net cash provided by financing activities 28,396 — 123,397 3,792 155,585 Net (decrease) increase in cash and cash equivalents (6,073 ) — (5,210 ) 33 (11,250 ) Cash and cash equivalents, beginning of period 29,115 — 9,757 2,431 41,303 Cash and cash equivalents, end of period $ 23,042 $ — $ 4,547 $ 2,464 $ 30,053 Six Months Ended September 30, 2016 NGL Energy NGL Energy Guarantor Non-Guarantor Consolidated OPERATING ACTIVITIES: Net cash used in operating activities $ (31,541 ) $ — $ (12,751 ) $ (12,107 ) $ (56,399 ) INVESTING ACTIVITIES: Capital expenditures — — (158,333 ) (1,347 ) (159,680 ) Purchases of pipeline capacity allocations — — (41,953 ) — (41,953 ) Acquisitions of businesses, including acquired working capital, net of cash acquired — — (113,297 ) — (113,297 ) Cash flows from commodity derivatives — — (25,015 ) — (25,015 ) Proceeds from sales of assets — — 379 17 396 Proceeds from sale of TLP common units — — 112,370 — 112,370 Distributions of capital from unconsolidated entities — — 5,233 — 5,233 Payments on loan for natural gas liquids facility — — 4,324 — 4,324 Loan to affiliate — — (1,700 ) — (1,700 ) Payments on loan to affiliate — — 655 — 655 Payment to terminate development agreement — — (16,875 ) — (16,875 ) Net cash used in investing activities — — (234,212 ) (1,330 ) (235,542 ) FINANCING ACTIVITIES: Proceeds from borrowings under revolving credit facilities — — 770,000 — 770,000 Payments on revolving credit facilities — — (595,500 ) — (595,500 ) Repurchases of senior notes (15,129 ) — — — (15,129 ) Payments on other long-term debt — — (4,080 ) (343 ) (4,423 ) Debt issuance costs (255 ) — (65 ) — (320 ) Contributions from partners (442 ) — — — (442 ) Contributions from noncontrolling interest owners — — — 966 966 Distributions to partners (83,707 ) — — — (83,707 ) Distributions to noncontrolling interest owners — — — (2,750 ) (2,750 ) Proceeds from sale of convertible preferred units and warrants, net of offering costs 235,018 — — — 235,018 Proceeds from sale of common units, net of offering costs 9,383 — — — 9,383 Payments for the early extinguishment of liabilities — — (25,884 ) — (25,884 ) Net changes in advances with consolidated entities (128,960 ) — 113,907 15,053 — Other — — (20 ) — (20 ) Net cash provided by financing activities 15,908 — 258,358 12,926 287,192 Net (decrease) increase in cash and cash equivalents (15,633 ) — 11,395 (511 ) (4,749 ) Cash and cash equivalents, beginning of period 25,749 — 784 1,643 28,176 Cash and cash equivalents, end of period $ 10,116 $ — $ 12,179 $ 1,132 $ 23,427

Organization and Operations (De

Organization and Operations (Details)	Sep. 30, 2016statepipelineterminal
Crude oil logistics
Organization and operations
Number of crude oil pipelines | pipeline	2
Liquids
Organization and operations
Number of owned terminals | terminal	18
Retail propane
Organization and operations
Number of states in which entity operates | state	27

Significant Accounting Polici40

Significant Accounting Policies - Revenue Recognition (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues [Abstract]
Amortization of contract liabilities to revenues	$ 1.2	$ 1.5	$ 2.5	$ 2.9

Significant Accounting Polici41

Significant Accounting Policies - Supplemental Cash Flow (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Accounting Policies [Abstract]
Value of common units issued in business combinations	$ 3,969	$ 0	$ 3,969	$ 11,367
Supplemental Cash Flow Information
Cash interest paid	29,711	26,323	58,869	57,495
Income taxes paid (net of income tax refunds)	$ 71	$ 533	$ 1,755	$ 4,616

Significant Accounting Polici42

Significant Accounting Policies - Inventories (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Mar. 31, 2016
Inventories
Crude oil	$ 86,495	$ 84,030
Natural gas liquids:
Propane	73,704	28,639
Butane	44,929	8,461
Other	5,936	6,011
Refined products:
Gasoline	126,821	80,569
Diesel	138,245	99,398
Renewables	34,328	52,458
Other	9,882	8,240
Total	$ 520,340	$ 367,806

Significant Accounting Polici43

Significant Accounting Policies - Investments in Unconsolidated Entities (Details) - USD ($) $ in Thousands	Apr. 01, 2016	Sep. 30, 2016	Jun. 03, 2016	Mar. 31, 2016
Investments in Unconsolidated Entities
Carrying Value		$ 190,662		$ 219,550
Water supply company
Investments in Unconsolidated Entities
Ownership interest				35.00%
Ownership interest acquired			65.00%
Glass Mountain
Investments in Unconsolidated Entities
Fair value in excess of historical net book value		$ 73,600
TLP
Investments in Unconsolidated Entities
Proceeds from sale of equity method investments	$ 112,400
Gain on disposal	$ 104,100
Crude oil logistics | Operating segment | Glass Mountain
Investments in Unconsolidated Entities
Ownership interest		50.00%
Carrying Value		$ 174,364		$ 179,594
Refined products and renewables | Operating segment | Ethanol production facility
Investments in Unconsolidated Entities
Ownership interest		19.00%
Carrying Value		$ 13,507		12,570
Refined products and renewables | Operating segment | TLP
Investments in Unconsolidated Entities
Ownership interest		0.00%
Carrying Value		$ 0		8,301
Water solutions | Operating segment | Water treatment and disposal facility
Investments in Unconsolidated Entities
Ownership interest		50.00%
Carrying Value		$ 2,235		2,238
Water solutions | Operating segment | Water supply company
Investments in Unconsolidated Entities
Ownership interest		100.00%
Carrying Value		$ 0		15,875
Retail propane | Operating segment | Retail propane company
Investments in Unconsolidated Entities
Ownership interest		50.00%
Carrying Value		$ 556		$ 972

Significant Accounting Polici44

Significant Accounting Policies - Other Noncurrent Assets (Details) $ in Thousands	Sep. 30, 2016USD ($)bbl	Mar. 31, 2016USD ($)bbl
Other Assets, Noncurrent [Abstract]
Loan receivable	$ 44,957	$ 49,827
Tank bottoms	42,044	42,044
Line fill	35,013	35,060
Other	95,725	49,108
Total	$ 217,739	$ 176,039
Number of barrels of refined product | bbl	366,212	366,212
Number of barrels of crude oil | bbl	486,473	487,104

Significant Accounting Polici45

Significant Accounting Policies - Accrued Expenses and Other Payables (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Mar. 31, 2016
Accounting Policies [Abstract]
Accrued compensation and benefits	$ 19,322	$ 40,517
Excise and other tax liabilities	56,147	59,455
Derivative liabilities	31,959	28,612
Accrued interest	19,594	20,543
Product exchange liabilities	7,045	5,843
Deferred gain on sale of general partner interest in TLP	30,113	30,113
Other	20,454	29,343
Total	$ 184,634	$ 214,426

Significant Accounting Polici46

Significant Accounting Policies Significant Accounting Policies - Sale of General Partner Interest in TLP (Details) - USD ($) $ in Thousands	Feb. 01, 2016	Sep. 30, 2016	Sep. 30, 2016	Mar. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred gain on sale of general partner interest in TLP		$ 30,113	$ 30,113	$ 30,113
General Partner Interest in TLP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred gain on disposal, amortization period	7 years
Recognized gain		7,600	15,100
General Partner Interest in TLP | Accrued expenses and other payables
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred gain on sale of general partner interest in TLP		30,100	30,100
General Partner Interest in TLP | Other noncurrent liabilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred gain on sale of general partner interest in TLP, noncurrent		$ 154,400	$ 154,400

Income (Loss) Per Common Unit47

Income (Loss) Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Mar. 31, 2016
Income (Loss) Per Common Unit
Net (loss) income	$ (66,658)	$ (6,100)	$ 116,095	$ (31,107)
Less: Net loss (income) attributable to noncontrolling interests	59	(3,497)	(5,774)	(7,847)
Net (loss) income attributable to NGL Energy Partners LP	(66,599)	(9,597)	110,321	(38,954)
Less: Distributions to preferred unitholders	(8,668)	0	(12,052)	0
Less: Net loss (income) allocated to general partner	45	(16,185)	(158)	(31,559)
Net (loss) income allocated to common unitholders	$ (75,222)	$ (25,782)	$ 98,111	$ (70,513)
Basic (loss) income per common unit (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.93	$ (0.67)
Diluted (loss) income per common unit (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.91	$ (0.67)
Basic weighted average common units outstanding (in units)	106,186,389	105,189,463	105,183,556	104,542,427
Diluted weighted average common units outstanding (in units)	106,186,389	105,189,463	107,997,549	104,542,427
Class A Convertible Preferred Units
Income (Loss) Per Common Unit
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS, units issued (in units)	19,942,169		19,942,169		0
Common units
Income (Loss) Per Common Unit
Basic (loss) income per common unit (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.93	$ (0.67)
Diluted (loss) income per common unit (in dollars per unit)	$ (0.71)	$ (0.25)	$ 0.91	$ (0.67)
Basic weighted average common units outstanding (in units)	106,186,389	105,189,463	105,183,556	104,542,427
Diluted weighted average common units outstanding (in units)	106,186,389	105,189,463	107,997,549	104,542,427
Common units | Warrant
Income (Loss) Per Common Unit
Weighted average number diluted shares outstanding adjustment (in units)			2,803,436
Performance awards | Common units
Income (Loss) Per Common Unit
Weighted average number diluted shares outstanding adjustment (in units)			10,621

Acquisitions - Water Solutions

Acquisitions - Water Solutions Facilities (Details) $ in Thousands	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2016USD ($)	Sep. 30, 2016USD ($)facility	Mar. 31, 2016USD ($)businessfacility
Business Acquisition [Line Items]
Goodwill		$ 1,467,955	$ 1,315,362
Water Solutions Acquisitions 2017 Acquisitions
Business Acquisition [Line Items]
Number of businesses acquired | facility		3
Cash paid		$ 26,900
Contingent consideration liability		2,600
Property, plant and equipment		15,021
Goodwill		18,933
Intangible assets		3,878
Accrued expenses and other payables		(1,239)
Other noncurrent liabilities		(9,697)
Fair value of net assets acquired		26,896
Accrued royalties		8,200
Water Solutions Facilities2016 Acquisitions Accounting Completed
Business Acquisition [Line Items]
Business combination number for which acquisition accounting is completed | facility			9
Adjustment, property, plant, and equipment	$ 700
Adjustment accrued expenses and other payables	$ 1,000
Retail propane 2016 acquisitions
Business Acquisition [Line Items]
Number of businesses acquired | business			5
Adjustment accrued expenses and other payables		300
Water solutions
Business Acquisition [Line Items]
Goodwill		$ 434,091	$ 290,915

Acquisitions Acquisitions - Acq

Acquisitions Acquisitions - Acquisition of Remaining Interest in Water Solutions Facilities (Details) - Water Solutions Facility 2017 Acquisitions $ in Millions	Sep. 15, 2016USD ($)facility
Business Acquisition [Line Items]
Ownership interest acquired	25.00%
Number of businesses acquired | facility	3
Cash paid	$ 10
Additional interest acquired	$ 7.4

Acquisitions - Water Pipeline C

Acquisitions - Water Pipeline Company (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Sep. 30, 2016	Jun. 03, 2016	Jan. 07, 2016
Business Acquisition [Line Items]
Adjustment, other noncurrent liabilities		$ 406
Water Pipeline Company
Business Acquisition [Line Items]
Ownership interest acquired			24.50%	57.125%
Additional interest acquired			$ 5,200
Water Pipeline Company | Rights-of-way
Business Acquisition [Line Items]
Intangible assets	$ 1,100
Water Solutions Facilities2016 Acquisitions Accounting Completed
Business Acquisition [Line Items]
Adjustment, property, plant, and equipment	$ 700
Adjustment, other noncurrent liabilities		$ 300

Acquisitions - Water Supply Com

Acquisitions - Water Supply Company (Details) - Water supply company - USD ($) $ in Thousands	Jun. 03, 2016	Sep. 30, 2016	Mar. 31, 2016
Business Acquisition [Line Items]
Ownership interest acquired	65.00%
Cash paid	$ 1,000
Ownership interest			35.00%
Fair value of equity method investment	800
Revaluation of investments excluding bargain purchase	(14,900)
Bargain purchase	$ 600
Current assets		$ 1,713
Property, plant and equipment		8,874
Intangible assets		14,472
Current liabilities		(2,765)
Notes payable-intercompany		(19,900)
Fair value of net assets acquired		$ 2,394

Acquisitions - Retail Propane B

Acquisitions - Retail Propane Businesses (Details) $ in Thousands	6 Months Ended	12 Months Ended
	Sep. 30, 2016USD ($)facilityshares	Mar. 31, 2016USD ($)business
Business Acquisition [Line Items]
General partners' capital account, units issued (in units) | shares	524
Common units issued, net of offering costs	$ 9,383
Goodwill	$ 1,467,955	$ 1,315,362
Retail propane 2017 acquisitions
Business Acquisition [Line Items]
Number of businesses acquired | facility	3
Cash paid	$ 72,100
Number of units issued | shares	218,617
Equity issued	$ 4,000
General partners' capital account, units issued (in units) | shares	219
Current assets	$ 6,282
Property, plant and equipment	30,576
Goodwill	9,419
Intangible assets	36,950
Accrued expenses and other payables	(5,555)
Advance payments received from customers	(1,587)
Fair value of net assets acquired	76,085
Retail propane 2016 acquisitions
Business Acquisition [Line Items]
Number of businesses acquired | business		5
Adjustment accrued expenses and other payables	300
Minimum | Retail propane 2017 acquisitions
Business Acquisition [Line Items]
Common units issued, net of offering costs	$ 100

Acquisitions - Delaware Basin W

Acquisitions - Delaware Basin Water Solutions Facilities (Details) - Delaware Basin Water Solutions Facilities	Aug. 24, 2015facility
Business Acquisition [Line Items]
Number of businesses acquired	4
Ownership interest acquired	50.00%

Property, Plant and Equipment54

Property, Plant and Equipment (Details) bbl in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Mar. 31, 2016USD ($)bbl
Property, Plant and Equipment
Property, plant and equipment, gross	$ 2,079,780		$ 2,079,780		$ 1,916,063
Accumulated depreciation	(324,364)		(324,364)		(266,491)
Net property, plant and equipment	1,755,416		1,755,416		1,649,572
Depreciation expense	28,703	$ 34,469	56,357	$ 70,264
Capitalized interest expense	1,069	549	4,804	690
Operating segment | Loss on disposal or impairment of assets, net
Property, Plant and Equipment
Loss on disposal of assets	8,500	$ 1,100	10,800	$ 1,700
Natural gas liquids terminal and storage assets
Property, Plant and Equipment
Property, plant and equipment, gross	168,754		$ 168,754		169,758
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
Refined products terminal assets and equipment
Property, Plant and Equipment
Useful life			20 years
Property, plant and equipment, gross	6,844		$ 6,844		6,844
Retail propane equipment
Property, Plant and Equipment
Property, plant and equipment, gross	227,442		$ 227,442		201,312
Retail propane equipment | Minimum
Property, Plant and Equipment
Useful life			2 years
Retail propane equipment | Maximum
Property, Plant and Equipment
Useful life			30 years
Vehicles and railcars
Property, Plant and Equipment
Property, plant and equipment, gross	194,291		$ 194,291		185,547
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
Property, plant and equipment, gross	535,255		$ 535,255		508,239
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
Property, plant and equipment, gross	140,245		$ 140,245		137,894
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			40 years
Barges and towboats
Property, Plant and Equipment
Property, plant and equipment, gross	89,973		$ 89,973		86,731
Barges and towboats | Minimum
Property, Plant and Equipment
Useful life			5 years
Barges and towboats | Maximum
Property, Plant and Equipment
Useful life			40 years
Information technology equipment
Property, Plant and Equipment
Property, plant and equipment, gross	42,218		$ 42,218		38,653
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
Property, plant and equipment, gross	123,005		$ 123,005		118,885
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
Property, plant and equipment, gross	50,132		$ 50,132		47,114
Tank bottoms
Property, Plant and Equipment
Property, plant and equipment, gross	20,105		20,105		20,355
Tank bottoms | Crude oil
Property, Plant and Equipment
Property, plant and equipment, gross	$ 19,120		$ 19,120		$ 19,348
Volume of property, plant and equipment | bbl	229		229		231
Tank bottoms | Other
Property, Plant and Equipment
Property, plant and equipment, gross	$ 985		$ 985		$ 1,007
Volume of property, plant and equipment | bbl	24		24		24
Other Machinery and Equipment
Property, Plant and Equipment
Property, plant and equipment, gross	$ 56,450		$ 56,450		$ 11,699
Other Machinery and Equipment | Minimum
Property, Plant and Equipment
Useful life			3 years
Other Machinery and Equipment | Maximum
Property, Plant and Equipment
Useful life			30 years
Construction in progress
Property, Plant and Equipment
Property, plant and equipment, gross	$ 425,066		$ 425,066		$ 383,032

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2016
Goodwill
Goodwill at the beginning of the period	$ 1,315,362		$ 1,315,362
Revisions to acquisition accounting (Note 4)			(421)
Acquisitions (Note 4)			28,352
Adjustment to initial impairment estimate			124,662
Goodwill at the end of the period		$ 1,315,362	1,467,955
Crude oil logistics
Goodwill
Goodwill at the beginning of the period	579,846		579,846
Goodwill at the end of the period		579,846	579,846
Water solutions
Goodwill
Goodwill at the beginning of the period	290,915		290,915
Revisions to acquisition accounting (Note 4)			(419)
Acquisitions (Note 4)			18,933
Adjustment to initial impairment estimate	124,700		124,662
Goodwill at the end of the period		290,915	434,091
Goodwill impairment charge		380,200
Liquids
Goodwill
Goodwill at the beginning of the period	266,046		266,046
Goodwill at the end of the period		266,046	266,046
Retail propane
Goodwill
Goodwill at the beginning of the period	127,428		127,428
Revisions to acquisition accounting (Note 4)			(2)
Acquisitions (Note 4)			9,419
Goodwill at the end of the period		127,428	136,845
Refined products and renewables
Goodwill
Goodwill at the beginning of the period	$ 51,127		51,127
Goodwill at the end of the period		$ 51,127	51,127
Water Solutions Acquisitions 2017 Acquisitions
Goodwill
Goodwill at the end of the period			18,933
Retail propane 2017 acquisitions
Goodwill
Goodwill at the end of the period			$ 9,419

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Thousands	Jun. 03, 2016	Sep. 30, 2016	Mar. 31, 2016
Amortizable
Gross Carrying Amount		$ 1,155,398	$ 1,085,958
Accumulated Amortization		356,314	316,878
Finite-Lived Intangible Assets, Net		799,084	769,080
INTANGIBLE ASSETS, net of accumulated amortization		1,190,147	1,148,890
Non-Amortizable
Total non-amortizable		391,063	379,810
Gross carrying amount of intangible assets		$ 1,546,461	1,465,768
Weighted average remaining amortization period		8 years 7 months 12 days
Water solutions
Amortizable
Amortizable life	2 years
Customer commitments
Non-Amortizable
Total non-amortizable		$ 310,000	310,000
Right-of-way and easements
Non-Amortizable
Total non-amortizable		47,721	47,190
Water rights
Non-Amortizable
Total non-amortizable		14,472	0
Trade names
Non-Amortizable
Total non-amortizable		18,870	22,620
Trade names | Operating segment | Water solutions
Non-Amortizable
Write off of intangible asset		5,200
Customer relationships
Amortizable
Gross Carrying Amount		883,896	852,118
Accumulated Amortization		274,111	233,838
Finite-Lived Intangible Assets, Net		$ 609,785	618,280
Customer relationships | Minimum
Amortizable
Amortizable life		3 years
Customer relationships | Maximum
Amortizable
Amortizable life		20 years
Pipeline capacity rights
Amortizable
Amortizable life		30 years
Gross Carrying Amount		$ 161,589	119,636
Accumulated Amortization		8,957	6,559
Finite-Lived Intangible Assets, Net		$ 152,632	113,077
Water facility development agreement
Amortizable
Amortizable life		5 years
Gross Carrying Amount		$ 0	14,000
Accumulated Amortization		0	7,700
Finite-Lived Intangible Assets, Net		0	6,300
Water facility development agreement | Operating segment | Water solutions
Non-Amortizable
Write off of intangible asset	$ 5,800
Executory contracts and other agreements
Amortizable
Gross Carrying Amount		22,713	23,920
Accumulated Amortization		19,699	21,075
Finite-Lived Intangible Assets, Net		$ 3,014	2,845
Executory contracts and other agreements | Minimum
Amortizable
Amortizable life		2 years
Executory contracts and other agreements | Maximum
Amortizable
Amortizable life		30 years
Non-compete agreements
Amortizable
Gross Carrying Amount		$ 31,784	20,903
Accumulated Amortization		15,101	13,564
Finite-Lived Intangible Assets, Net		$ 16,683	7,339
Non-compete agreements | Minimum
Amortizable
Amortizable life		2 years
Non-compete agreements | Maximum
Amortizable
Amortizable life		32 years
Trade names
Amortizable
Gross Carrying Amount		$ 15,439	15,439
Accumulated Amortization		12,882	12,034
Finite-Lived Intangible Assets, Net		$ 2,557	3,405
Trade names | Minimum
Amortizable
Amortizable life		1 year
Trade names | Maximum
Amortizable
Amortizable life		10 years
Debt issuance costs
Amortizable
Amortizable life		3 years
Gross Carrying Amount		$ 39,977	39,942
Accumulated Amortization		25,564	22,108
Finite-Lived Intangible Assets, Net		$ 14,413	$ 17,834

Intangible Assets - Amortizatio

Intangible Assets - Amortization (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Mar. 31, 2016
Amortization related to intangible assets
Amortization expense	$ 25,380	$ 25,461	$ 49,953	$ 52,683
Future amortization expense of intangible assets
2017 (six months)	51,028		51,028
2,018	98,717		98,717
2,019	89,701		89,701
2,020	82,185		82,185
2,021	69,422		69,422
Thereafter	408,031		408,031
Total	799,084		799,084		$ 769,080
Depreciation and amortization
Amortization related to intangible assets
Amortization expense	21,900	22,291	43,152	46,328
Cost of sales
Amortization related to intangible assets
Amortization expense	1,749	1,700	3,345	3,401
Interest expense
Amortization related to intangible assets
Amortization expense	$ 1,731	$ 1,470	$ 3,456	$ 2,954

Long-Term Debt (Details)

Long-Term Debt (Details) $ in Thousands	1 Months Ended	3 Months Ended			6 Months Ended
	Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Mar. 31, 2016USD ($)	Jul. 09, 2014USD ($)	Oct. 16, 2013USD ($)	Jun. 19, 2012USD ($)
Long-Term Debt
Face amount		$ 3,084,536			$ 3,084,536		$ 2,936,244
Face amount, current portion		8,046			8,046		7,907
Face amount, long-term		3,076,490			3,076,490		2,928,337
Unamortized debt issuance costs		(13,482)			(13,482)		(15,500)
Book value		3,071,054			3,071,054		2,920,744
Book value, current		8,046			8,046		7,907
LONG-TERM DEBT, net of debt issuance costs and current maturities		3,063,008			3,063,008		2,912,837
Amortization of debt issuance costs		1,000		$ 800	1,800	$ 1,600
Repurchases of senior notes					15,129	$ 0
Expected Future Amortization of Debt Issuance Costs [Abstract]
2017 (six months)		1,619			1,619
2,018		3,229			3,229
2,019		3,226			3,226
2,020		2,236			2,236
2,021		1,827			1,827
Thereafter		1,345			1,345
Total		13,482			13,482
Revolving Credit Facility
Long-Term Debt
Long-term line of credit		$ 2,000,000			$ 2,000,000
Interest rate		2.83%			2.83%
Revolving Credit Facility
Long-Term Debt
Maximum borrowing capacity		$ 2,484,000			$ 2,484,000
Increased borrowing capacity with the exercise of accordion feature		150,000			$ 150,000
Actual leverage ratio					4.15
Actual interest coverage ratio					4.60
Revolving Credit Facility | Minimum
Long-Term Debt
Commitments fees charged on unused capacity					0.38%
Interest coverage ratio					2.75
Revolving Credit Facility | Maximum
Long-Term Debt
Commitments fees charged on unused capacity					0.50%
Leverage ratio					4.75
Revolving Credit Facility | Alternate base rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base					0.50%
Revolving Credit Facility | Alternate base rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base					1.75%
Revolving Credit Facility | LIBOR option
Long-Term Debt
Interest rate margin added to variable rate base					2.25%
Reference rate					0.53%
Revolving Credit Facility | LIBOR option | Minimum
Long-Term Debt
Interest rate margin added to variable rate base					1.50%
Revolving Credit Facility | LIBOR option | Maximum
Long-Term Debt
Interest rate margin added to variable rate base					2.75%
Revolving Credit Facility | Prime Rate
Long-Term Debt
Interest rate margin added to variable rate base					1.25%
Reference rate					3.50%
Revolving Credit Facility | Expansion Capital Facility
Long-Term Debt
Face amount		1,312,000			$ 1,312,000		1,229,500
Unamortized debt issuance costs		0			0		0
Book value		1,312,000			1,312,000		1,229,500
Long-term line of credit		1,446,000			1,446,000
Revolving Credit Facility | Working Capital Facility
Long-Term Debt
Face amount		710,500			710,500		618,500
Unamortized debt issuance costs		0			0		0
Book value		710,500			710,500		618,500
Maximum borrowing capacity		1,038,000			1,038,000
Outstanding letters of credit		$ 75,300			$ 75,300
Revolving Credit Facility | Letters of credit
Long-Term Debt
Fixed interest rate		2.25%			2.25%
5.125% Senior Notes due 2019
Long-Term Debt
Face amount		$ 383,467			$ 383,467		388,467
Fixed interest rate		5.125%			5.125%			5.125%
Unamortized debt issuance costs		$ (3,871)			$ (3,871)		(4,681)
Book value		379,596			379,596		383,786
Debt issued								$ 400,000
Repurchase amount		5,000			5,000
Repurchases of senior notes		3,100
Gain on early extinguishment of debt		1,800
Write off of debt issuance cost		100
6.875% Senior Notes due 2021
Long-Term Debt
Face amount		$ 369,063			$ 369,063		388,289
Fixed interest rate		6.875%			6.875%				6.875%
Unamortized debt issuance costs		$ (6,433)			$ (6,433)		(7,545)
Book value		362,630			362,630		380,744
Debt issued									$ 450,000
Repurchase amount			$ 19,200
Repurchases of senior notes (excluding payments of accrued interest)			12,000
Gain on early extinguishment of debt			6,800
Write off of debt issuance cost			$ 400
6.650% Senior Notes due 2022
Long-Term Debt
Face amount		$ 250,000			$ 250,000		250,000
Fixed interest rate		6.65%			6.65%					6.65%
Unamortized debt issuance costs		$ (3,055)			$ (3,055)		(3,166)
Book value		246,945			246,945		246,834
Debt issued										$ 250,000
Repayments in semi-annual installments					25,000
7.50% Senior Notes due 2023 | Subsequent Event
Long-Term Debt
Fixed interest rate	7.50%
Debt issued	$ 700,000
Proceeds from unsecured notes payable	$ 688,000
Other long-term debt
Long-Term Debt
Face amount		59,506			59,506		61,488
Unamortized debt issuance costs		(123)			(123)		(108)
Book value		$ 59,383			$ 59,383		$ 61,380
Other long-term debt | Minimum
Long-Term Debt
Fixed interest rate		1.17%			1.17%
Other long-term debt | Maximum
Long-Term Debt
Fixed interest rate		7.08%			7.08%

Long-Term Debt - Maturity Sched

Long-Term Debt - Maturity Schedule (Details) $ in Thousands	Sep. 30, 2016USD ($)
Maturities
2017 (six months)	$ 3,405
2,018	33,014
2,019	2,079,357
2,020	439,839
2,021	84,728
Thereafter	444,193
Total	3,084,536
Revolving Credit Facility
Maturities
2,019	2,022,500
Total	2,022,500
5.125% Senior Notes due 2019
Maturities
2,020	383,467
Total	383,467
6.875% Senior Notes due 2021
Maturities
Thereafter	369,063
Total	369,063
6.650% Senior Notes due 2022
Maturities
2,018	25,000
2,019	50,000
2,020	50,000
2,021	50,000
Thereafter	75,000
Total	250,000
Other long-term debt
Maturities
2017 (six months)	3,405
2,018	8,014
2,019	6,857
2,020	6,372
2,021	34,728
Thereafter	130
Total	$ 59,506

Income Taxes (Details)

Income Taxes (Details)	6 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Minimum percentage of qualifying income of non taxable subsidiaries	90.00%

Commitments and Contingencies -

Commitments and Contingencies - Environmental Matters (Details) $ in Millions	Sep. 30, 2016USD ($)
Environmental matter
Environmental matters liability	$ 2.2

Commitments and Contingencies62

Commitments and Contingencies - Asset Retirement Obligations (Details) $ in Thousands	6 Months Ended
	Sep. 30, 2016USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	$ 5,574
Liabilities incurred	406
Accretion expense	207
Balance at end of period	$ 6,187

Commitments and Contingencies63

Commitments and Contingencies - Operating Leases (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Future minimum lease payments
2017 (six months)	$ 67,837		$ 67,837
2,018	122,935		122,935
2,019	101,047		101,047
2,020	90,112		90,112
2,021	80,457		80,457
Thereafter	135,486		135,486
Total	597,874		597,874
Rental expense	$ 27,000	$ 33,300	$ 56,900	$ 67,100

Commitments and Contingencies64

Commitments and Contingencies - Pipeline Capacity Agreements (Details) - Pipeline Capacity Agreements $ in Thousands	Sep. 30, 2016USD ($)
Future minimum throughput payments
2017 (six months)	$ 26,008
2,018	52,082
2,019	52,170
2,020	42,418
Total	$ 172,678

Commitments and Contingencies65

Commitments and Contingencies - Sales and Purchase Contracts (Details) gal in Thousands, bbl in Thousands, $ in Thousands	Sep. 30, 2016USD ($)bblgal
Prepaid expenses and other current assets
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	$ 41,000
Accrued expenses and other payables
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	$ 29,600
Natural gas liquids
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price purchase commitments (in gallons/barrels) | gal	35,592
Index-price purchase commitments (in gallons/barrels) | gal	587,044
Fixed-price sale commitments (in gallons/barrels) | gal	163,546
Index-price sale commitments (in gallons/barrels) | gal	414,042
Fixed-price purchase commitments	$ 18,710
Index-price purchase commitments	347,020
Fixed-price sale commitments	105,868
Index-price sale commitments	$ 317,983
Crude oil
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price purchase commitments (in gallons/barrels) | bbl	1,993
Index-price purchase commitments (in gallons/barrels) | bbl	14,466
Fixed-price sale commitments (in gallons/barrels) | bbl	3,415
Index-price sale commitments (in gallons/barrels) | bbl	12,953
Fixed-price purchase commitments	$ 88,079
Index-price purchase commitments	655,273
Fixed-price sale commitments	152,584
Index-price sale commitments	$ 637,731

Equity - Partnership Equity (De

Equity - Partnership Equity (Details)	3 Months Ended	6 Months Ended
	Mar. 31, 2016	Sep. 30, 2016
Equity
General partner interest	0.10%	0.10%
Limited partner interest	99.90%	99.90%
Common units
Equity
General partner interest		0.10%
Limited partner interest		99.90%

Equity - Distribution Policy (D

Equity - Distribution Policy (Details) - USD ($) $ / shares in Units, $ in Thousands	Nov. 14, 2016	Oct. 20, 2016	Aug. 12, 2016	Jul. 22, 2016	May 13, 2016	Apr. 21, 2016
Partners Capital Accounts [Line Items]
Amount Per Unit (in dollars per share)				$ 0.390000		$ 0.390000
Amount Paid/Payable to Limited Partners			$ 41,146		$ 40,626
Amount Paid/Payable to General Partner			$ 71		$ 70
Subsequent Event
Partners Capital Accounts [Line Items]
Amount Per Unit (in dollars per share)		$ 0.390000
Amount Paid/Payable to Limited Partners	$ 41,907
Amount Paid/Payable to General Partner	$ 72

Equity - Class A Convertible Pr

Equity - Class A Convertible Preferred Units (Details) - USD ($)	Oct. 20, 2016	Jun. 24, 2016	May 11, 2016	Apr. 21, 2016	Sep. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Jul. 22, 2016	Jun. 23, 2016
Equity-Based Incentive Compensation
Proceeds from issuance of preferred units		$ 140,000,000	$ 100,000,000
Preferred units, issued (in units)		11,632,932	8,309,237
Outstanding (in units)		2,552,149	1,822,963		4,375,112	4,375,112
Exercise price (in dollars per unit)		$ 0.01
Proceeds from sale of convertible preferred units and warrants, net of offering costs						$ 235,018,000	$ 0
Oaktree Capital Management L.P.
Equity-Based Incentive Compensation
Authorized amount				$ 200,000,000					$ 240,000,000
Oaktree Capital Management L.P. | Class A Convertible Preferred Units
Equity-Based Incentive Compensation
Stated interest rate				10.75%
Days after quarter end distribution paid				45 days
Dividends declared, amount								$ 1,800,000
Initial conversion price (in dollars per unit)				$ 12.035
Reset conversion price, trading days used for adjustment				15 days
Reset conversion price (in dollars per unit)				$ 5
Number of days within closing date of registration statement required to file within				180 days
Number of days after closing date registration statement declared effective				360 days
Class of warrant or right, term				8 years
Proceeds from sale of convertible preferred units and warrants, net of offering costs				$ 235,000,000
Payments of stock issuance costs				5,000,000
Proceeds from sale of convertible preferred units and warrants, net of offering costs				186,400,000
Allocation of value to beneficial conversion feature of Class A convertible preferred units				$ 131,500,000
Conversion period				3 years
Accretion of beneficial conversion					$ 2,200,000	$ 3,800,000
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Warrant
Equity-Based Incentive Compensation
Proceeds from sale of convertible preferred units and warrants, net of offering costs				$ 48,600,000
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | From and after the first anniversary of the original issue date
Equity-Based Incentive Compensation
Percentage convertible				33.33%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | From and after the second anniversary of the original issue date
Equity-Based Incentive Compensation
Percentage convertible				33.33%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | From and after the third anniversary of the original issue date
Equity-Based Incentive Compensation
Percentage convertible				33.33%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after first, but prior to the second anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.40
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the second, but prior to the third anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.15
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the third, but prior to the eighth anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.10
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the eighth anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.01
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Prior to the first anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.40
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the first but prior to the second anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.30
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | On or after the second anniversary of the closing date
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.20
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Thereafter
Equity-Based Incentive Compensation
Preferred stock redemption premium percentage				1.01
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | First 60 day period following the effectiveness deadline
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.25%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Each subsequent 30 day period
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.25%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | 61-91 days
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.50%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | 91-120 days
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.75%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Thereafter
Equity-Based Incentive Compensation
Percentage increase in dividend rate				1.00%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | First six-month period
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.25%
Payment default period				6 months
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Second six-month period
Equity-Based Incentive Compensation
Percentage increase in dividend rate				0.25%
Payment default period				6 months
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Maximum
Equity-Based Incentive Compensation
Stated interest rate				11.25%
Oaktree Capital Management L.P. | Class A Convertible Preferred Units | Maximum | Thereafter
Equity-Based Incentive Compensation
Percentage increase in dividend rate				1.00%
Subsequent Event | Oaktree Capital Management L.P. | Class A Convertible Preferred Units
Equity-Based Incentive Compensation
Preferred units, distributions declared	$ 6,400,000

Equity Equity - At-The-Market (

Equity Equity - At-The-Market ("ATM") Offering (Details) - USD ($)	Aug. 24, 2016	Nov. 07, 2016	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2016
Equity
Aggregate offering price	$ 200,000,000
Limited partners, common units issued (in units)			524,000
Proceeds from at the market program			$ 9,600,000
General partners' capital account, units issued (in units)			524		524
Common units issued, net of offering costs					$ 9,383,000
General partner interest				0.10%	0.10%
Aggregate offering price remaining for sale			$ 190,400,000
Common units
Equity
General partner interest					0.10%
Subsequent Event
Equity
Proceeds from at the market program		$ 3,700,000
Shares issued under the ATM Program		192,000
Minimum
Equity
Limited partners' offering costs (less than $0.1 million)			$ 100,000		$ 100,000
Minimum | Subsequent Event
Equity
Limited partners' offering costs (less than $0.1 million)		$ 100,000

Equity - Award Activity (Detai

Equity - Award Activity (Details) - USD ($)	6 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016
Equity-Based Incentive Compensation
Equity	$ 1,955,314,000		$ 1,694,065,000
Award activity
Units granted (in units)	1,008,091
Restricted units
Equity-Based Incentive Compensation
Distributions on restricted units during the vesting period	$ 0
Service awards
Award activity
Unvested restricted units at the beginning of the period (in units)	2,297,132
Units granted (in units)	3,048,100
Units vested and issued (in units)	(2,340,082)
Units forfeited (in units)	(322,100)
Unvested restricted units at the end of the period (in units)	2,683,050
Service awards | Taxes withheld upon the vesting of restricted units
Equity-Based Incentive Compensation
Share-based arrangements liability reclassified to equity		$ (25,600,000)
Equity		25,600,000
Performance awards
Award activity
Unvested restricted units at the beginning of the period (in units)	637,382
Units granted (in units)	932,309
Units forfeited (in units)	(380,691)
Unvested restricted units at the end of the period (in units)	1,189,000
Performance awards | Taxes withheld upon the vesting of restricted units
Equity-Based Incentive Compensation
Share-based arrangements liability reclassified to equity		(1,800,000)
Equity		$ 1,800,000

Equity - Service Awards Vesting

Equity - Service Awards Vesting Schedule (Details) - Service awards	6 Months Ended
	Sep. 30, 2016shares
Equity-Based Incentive Compensation
Number of units scheduled to vest (in units)	2,340,082
Unvested restricted units at the beginning of the period (in units)	2,297,132
2017 (six months)
Equity-Based Incentive Compensation
Number of units scheduled to vest (in units)	10,000
2,018
Equity-Based Incentive Compensation
Number of units scheduled to vest (in units)	887,350
2,019
Equity-Based Incentive Compensation
Number of units scheduled to vest (in units)	894,800
Thereafter
Equity-Based Incentive Compensation
Number of units scheduled to vest (in units)	890,900

Equity - Service Awards Expense

Equity - Service Awards Expense (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Mar. 31, 2016
Estimated equity-based compensation expense
Units granted (in units)			1,008,091
Accrued expenses related to bonuses granted in common units			$ 2,200		$ 16,800
Compensation cost			19,000
Service awards
Equity-Based Incentive Compensation
Expense recorded	$ 25,800	$ 14,900	46,700	$ 33,400
Estimated equity-based compensation expense
2017 (six months)			9,329
2,018			12,239
2,019			8,853
Thereafter			2,317
Total			$ 32,738
Units granted (in units)			3,048,100
Performance awards
Estimated equity-based compensation expense
2017 (six months)			$ 4,138
2,018			6,197
2,019			3,232
Thereafter			655
Total			$ 14,222
Units granted (in units)			932,309
Compensation cost	$ 1,600	$ 300	$ 3,100	$ 18,100

Equity - Performance Awards (De

Equity - Performance Awards (Details) - USD ($)	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 30, 2016	Mar. 31, 2016
Equity-Based Incentive Compensation
Compensation cost			$ 19,000,000
Other disclosures
Maximum number of common units that may be delivered under the LTIP as a percentage of issued and outstanding common units			10.00%
Incremental amount that the maximum common units deliverable may automatically increase under the LTIP, expressed as a percentage of issued and outstanding common units			10.00%
Number of common units available for issuance under the LTIP (in units)	1,100,000		1,100,000
Performance awards
Equity-Based Incentive Compensation
Stock issued during period, shares, restricted stock award	1,189,000		1,189,000			637,382
Compensation cost	$ 1,600,000	$ 300,000	$ 3,100,000	$ 18,100,000
Estimated equity-based compensation expense
2017 (six months)			4,138,000
2,018			6,197,000
2,019			3,232,000
Thereafter			655,000
Total			$ 14,222,000
Performance awards | Less than 50%
Equity-Based Incentive Compensation
Percentage of entities outperformed, upper limit			50.00%
Percentage of awards to vest			0.00%
Performance awards | 50%-75% | Minimum
Equity-Based Incentive Compensation
Percentage of entities outperformed, lower limit			50.00%
Percentage of awards to vest			50.00%
Performance awards | 50%-75% | Maximum
Equity-Based Incentive Compensation
Percentage of entities outperformed, upper limit			75.00%
Percentage of awards to vest			100.00%
Performance awards | 75%-90% | Minimum
Equity-Based Incentive Compensation
Percentage of entities outperformed, lower limit			75.00%
Percentage of awards to vest			100.00%
Performance awards | 75%-90% | Maximum
Equity-Based Incentive Compensation
Percentage of entities outperformed, upper limit			90.00%
Percentage of awards to vest			200.00%
Performance awards | Greater than 90%
Equity-Based Incentive Compensation
Percentage of entities outperformed, lower limit			90.00%
Percentage of awards to vest			200.00%
Performance awards | July 1, 2016
Equity-Based Incentive Compensation
Fair value of unvested awards					$ 0

Fair Value of Financial Instr74

Fair Value of Financial Instruments - Fair Value of Commodity Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Mar. 31, 2016
Prepaid expenses and other current assets
Derivative assets (liabilities)
Net (liability) asset	$ 41,000
Accrued expenses and other payables
Derivative assets (liabilities)
Net (liability) asset	29,600
Commodity contracts
Assets:
Derivative Assets	44,967	$ 80,061
Netting of counterparty contracts, assets	(3,091)	(3,384)
Net cash collateral provided (held)	21	(18,176)
Commodity derivatives in condensed consolidated balance sheet, assets	41,897	58,501
Liabilities:
Derivative Liabilities	(72,513)	(32,595)
Netting of counterparty contracts, liabilities	3,091	3,384
Cash collateral provided (held)	37,463	599
Commodity derivatives in condensed consolidated balance sheet, liabilities	(31,959)	(28,612)
Derivative assets (liabilities)
Net (liability) asset	9,938	29,889
Commodity contracts | Prepaid expenses and other current assets
Derivative assets (liabilities)
Net (liability) asset	41,897	58,501
Commodity contracts | Accrued expenses and other payables
Derivative assets (liabilities)
Net (liability) asset	(31,959)	(28,612)
Level 1 | Commodity contracts
Assets:
Derivative Assets	2,512	47,361
Liabilities:
Derivative Liabilities	(40,260)	(3,983)
Level 2 | Commodity contracts
Assets:
Derivative Assets	42,455	32,700
Liabilities:
Derivative Liabilities	$ (32,253)	$ (28,612)

Fair Value of Financial Instr75

Fair Value of Financial Instruments - Derivative Contract Positions (Details) bbl in Thousands, $ in Thousands	Sep. 30, 2016USD ($)bbl	Mar. 31, 2016USD ($)bbl
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (27,546)	$ 47,466
Net cash collateral provided (held)	37,484	(17,577)
Net commodity derivative asset in condensed consolidated balance sheet	9,938	29,889
Cross-commodity
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 1,465	$ 1,663
Cross-commodity | Long
Derivative contract information
Total Notional Units (Barrels) | bbl	126	251
Crude oil fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (3,041)	$ (3,655)
Crude oil fixed-price | Short
Derivative contract information
Total Notional Units (Barrels) | bbl	588	1,583
Propane fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ 518	$ (592)
Propane fixed-price | Long
Derivative contract information
Total Notional Units (Barrels) | bbl	462	540
Refined products fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (22,607)	$ 48,557
Refined products fixed-price | Short
Derivative contract information
Total Notional Units (Barrels) | bbl	5,628	5,355
Other
Derivative contract information
Fair Value of Net Assets (Liabilities)	$ (3,881)	$ 1,493

Fair Value of Financial Instr76

Fair Value of Financial Instruments - Gains (Losses) From Commodity Derivatives (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Net gains (losses) on derivatives	$ 14.7	$ 85.8	$ (45)	$ 44.5

Fair Value of Financial Instr77

Fair Value of Financial Instruments - Interest Rate Risk (Details) - Revolving Credit Facility $ in Billions	Sep. 30, 2016USD ($)
Interest Rate Risk
Outstanding debt	$ 2
Interest rate	2.83%

Fair Value of Financial Instr78

Fair Value of Financial Instruments - Fair Value of Fixed-Rate Notes (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Jul. 09, 2014	Oct. 16, 2013	Jun. 19, 2012
5.125% Senior Notes due 2019
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 360,459
Fixed interest rate	5.125%	5.125%
6.875% Senior Notes due 2021
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 349,995
Fixed interest rate	6.875%		6.875%
6.650% Senior Notes due 2022
Fair Value of Fixed - Rate Notes
Fair value of fixed - rate notes	$ 253,838
Fixed interest rate	6.65%			6.65%

Segments (Details)

Segments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Mar. 31, 2016
Segment information
Revenues	$ 3,045,538	$ 3,193,195	$ 5,767,508	$ 6,731,664
Corporate and Other	248	0	515	0
Depreciation and amortization	50,603	56,761	99,509	116,592
Operating income (loss)	(35,828)	18,298	158,072	17,088
Additions to property, plant and equipment and intangible assets	137,509	159,203	267,089	323,268
Long-lived assets, net	4,413,518		4,413,518		$ 4,113,824
Total assets	6,073,918		6,073,918		5,560,155
Operating segment | Crude oil logistics
Segment information
Revenues	349,885	1,007,578	775,836	2,335,362
Depreciation and amortization	9,025	10,053	17,993	20,055
Operating income (loss)	(19,039)	(75)	(19,664)	11,885
Additions to property, plant and equipment and intangible assets	32,397	44,384	104,702	107,023
Long-lived assets, net	1,720,278		1,720,278		1,679,027
Total assets	2,318,083		2,318,083		2,197,113
Operating segment | Crude oil logistics | Crude oil sales
Segment information
Revenues	341,981	997,106	756,600	2,309,889
Operating segment | Crude oil logistics | Crude oil transportation and other
Segment information
Revenues	9,172	12,746	22,106	31,695
Operating segment | Water solutions
Segment information
Revenues	39,733	47,494	75,486	101,787
Depreciation and amortization	25,129	22,416	49,563	43,262
Operating income (loss)	(4,430)	18,257	75,034	28,704
Additions to property, plant and equipment and intangible assets	25,237	72,531	68,353	133,020
Long-lived assets, net	1,316,196		1,316,196		1,162,405
Total assets	1,354,786		1,354,786		1,236,875
Operating segment | Water solutions | Service fees
Segment information
Revenues	28,528	35,203	54,225	71,941
Operating segment | Water solutions | Recovered hydrocarbons
Segment information
Revenues	5,681	10,746	12,877	26,564
Operating segment | Water solutions | Other revenues
Segment information
Revenues	5,524	1,545	8,384	3,282
Operating segment | Liquids
Segment information
Revenues	234,260	258,992	439,309	507,977
Depreciation and amortization	4,425	2,745	8,874	7,749
Operating income (loss)	8,384	20,370	8,327	19,899
Additions to property, plant and equipment and intangible assets	6,693	18,886	13,161	36,064
Long-lived assets, net	575,963		575,963		572,081
Total assets	785,303		785,303		693,872
Operating segment | Liquids | Other revenues
Segment information
Revenues	8,075	10,122	15,222	19,622
Operating segment | Liquids | Propane sales
Segment information
Revenues	101,613	98,770	198,084	204,260
Operating segment | Liquids | Other product sales
Segment information
Revenues	135,700	160,836	249,435	308,347
Operating segment | Retail propane
Segment information
Revenues	51,090	53,206	111,477	117,653
Depreciation and amortization	10,705	8,909	20,392	17,615
Operating income (loss)	(8,717)	(1,765)	(11,219)	(2,465)
Additions to property, plant and equipment and intangible assets	71,425	15,814	77,974	22,709
Long-lived assets, net	549,429		549,429		483,330
Total assets	611,340		611,340		538,267
Operating segment | Retail propane | Other revenues
Segment information
Revenues	9,331	9,409	17,638	17,724
Operating segment | Retail propane | Propane sales
Segment information
Revenues	36,170	36,119	77,811	79,304
Operating segment | Retail propane | Distillate sales
Segment information
Revenues	5,589	7,678	16,044	20,625
Operating segment | Refined products and renewables
Segment information
Revenues	2,370,322	1,825,925	4,364,885	3,668,885
Depreciation and amortization	416	11,152	833	25,327
Operating income (loss)	11,387	(5,244)	161,156	27,776
Additions to property, plant and equipment and intangible assets	1,143	7,588	1,167	23,283
Long-lived assets, net	219,157		219,157		180,783
Total assets	904,386		904,386		765,806
Operating segment | Refined products and renewables | Service fees
Segment information
Revenues	(121)	28,739	11,145	56,812
Operating segment | Refined products and renewables | Refined products sales
Segment information
Revenues	2,274,715	1,704,259	4,151,572	3,413,208
Operating segment | Refined products and renewables | Renewables sales
Segment information
Revenues	95,830	93,189	202,312	199,342
Operating segment | Corporate and other
Segment information
Depreciation and amortization	903	1,486	1,854	2,584
Operating income (loss)	(23,413)	(13,245)	(55,562)	(68,711)
Additions to property, plant and equipment and intangible assets	614	0	1,732	1,169
Long-lived assets, net	32,495		32,495		36,198
Total assets	100,020		100,020		$ 128,222
Elimination of intersegment sales | Crude oil logistics
Segment information
Revenues	(1,268)	(2,274)	(2,870)	(6,222)
Elimination of intersegment sales | Liquids
Segment information
Revenues	(11,128)	(10,736)	(23,432)	(24,252)
Elimination of intersegment sales | Retail propane
Segment information
Revenues	0	0	(16)	0
Elimination of intersegment sales | Refined products and renewables
Segment information
Revenues	$ (102)	$ (262)	$ (144)	$ (477)

Transactions with Affiliates (D

Transactions with Affiliates (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 03, 2016	Mar. 31, 2016
Transactions with Affiliates
Accounts receivable-affiliates	$ 3,540			$ 3,540			$ 15,625
Accounts payable to affiliates	6,244			6,244			7,193
Water supply company
Transactions with Affiliates
Ownership interest acquired						65.00%
SemGroup
Transactions with Affiliates
Sales to related party	3,513		$ 4,593	3,584	$ 42,031
Purchases from related party	1,938		6,478	3,963	45,303
Accounts receivable-affiliates	3,401			3,401			1,166
Accounts payable to affiliates	4,015			4,015			1,823
Equity method investees
Transactions with Affiliates
Sales to related party	95		1,696	500	3,086
Purchases from related party	27,345		24,816	57,992	55,764
Accounts receivable-affiliates	0			0			14,446
Accounts payable to affiliates	1,155			1,155			3,947
Loan receivable from affiliates							22,300
Loan payment received from investee		$ 700
Impairment of loan receivable from investee		$ 1,700
Equity method investees | Loan Agreement
Transactions with Affiliates
Loan receivable from affiliates	1,700			$ 1,700
Loan agreement successive extension period				1 year
Entities affiliated with management
Transactions with Affiliates
Increase in property, plant and equipment				$ 10,500
Sales to related party	75		91	152	198
Purchases from related party	3,493		$ 16,214	11,736	$ 23,394
Accounts receivable-affiliates	139			139			13
Accounts payable to affiliates	$ 1,074			$ 1,074			$ 1,423

Other Matters (Details)

Other Matters (Details) - USD ($) $ in Thousands	Jun. 03, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Segment information
Purchases of pipeline capacity allocations				$ 41,953	$ 0
Payment to terminate contract				16,875	0
Payments for the early extinguishment of liabilities				25,884	0
Gain on early extinguishment of liabilities		$ 938	$ 0	30,890	0
Loss on disposal or impairment of assets, net		$ (852)	$ (1,291)	203,467	$ (1,712)
Water solutions
Segment information
Payment to terminate contract	$ 49,600
Amortizable life	2 years
Increase in property, plant and equipment	$ 1,200
Intangible asset additions	3,300
Noncontrolling interest, increase from business combination	2,800
Payments for the early extinguishment of liabilities	25,500			46,800
Release of liabilities, contract termination	16,900
Gain on early extinguishment of liabilities				21,300
Loss on disposal or impairment of assets, net				$ 22,700
Water solutions | Accrued expenses and other payables
Segment information
Payment to terminate contract	$ 2,100

Subsequent Events (Details)

Subsequent Events (Details) - 7.50% Senior Notes due 2023 - Subsequent Event $ in Millions	1 Months Ended
	Oct. 31, 2016USD ($)
Subsequent events
Debt issued	$ 700
Proceeds from unsecured notes payable	688
Senior unsecured notes purchaser's discount	10.5
Senior notes offering costs	$ 1.5
Fixed interest rate	7.50%

Condensed Consolidating Guara83

Condensed Consolidating Guarantor and Non-Guarantor Financial Information - Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Mar. 31, 2015
CURRENT ASSETS:
Cash and cash equivalents	$ 23,427	$ 28,176	$ 30,053	$ 41,303
Accounts receivable - trade, net of allowance for doubtful accounts	592,074	521,014
Accounts receivable-affiliates	3,540	15,625
Inventories	520,340	367,806
Prepaid expenses and other current assets	110,918	95,859
Total current assets	1,250,299	1,028,480
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,755,416	1,649,572
GOODWILL	1,467,955	1,315,362
INTANGIBLE ASSETS, net of accumulated amortization	1,190,147	1,148,890
INVESTMENTS IN UNCONSOLIDATED ENTITIES	190,662	219,550
LOAN RECEIVABLE-AFFILIATE	1,700	22,262
OTHER NONCURRENT ASSETS	217,739	176,039
Total assets	6,073,918	5,560,155
CURRENT LIABILITIES:
Accounts payable-trade	512,104	420,306
Accounts payable-affiliates	6,244	7,193
Accrued expenses and other payables	184,634	214,426
Advance payments received from customers	87,825	56,185
Current maturities of long-term debt	8,046	7,907
Total current liabilities	798,853	706,017
LONG-TERM DEBT, net of debt issuance costs and current maturities	3,063,008	2,912,837
OTHER NONCURRENT LIABILITIES	198,001	247,236
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS	58,742	0
EQUITY :
Partners' equity	1,926,861	1,656,515
Accumulated other comprehensive loss	(642)	(157)
Noncontrolling interests	29,095	37,707
Total equity	1,955,314	1,694,065
Total liabilities, convertible preferred units and equity	6,073,918	5,560,155
Liabilities and Equity		5,560,155
Reportable Entity | NGL Energy Partners LP (Parent)
CURRENT ASSETS:
Cash and cash equivalents	10,116	25,749	23,042	29,115
Total current assets	10,116	25,749
INTANGIBLE ASSETS, net of accumulated amortization	0	0
NET INTERCOMPANY RECEIVABLES (PAYABLES)	1,290,616	1,404,479
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,689,633	1,254,383
Total assets	2,990,365	2,684,611
CURRENT LIABILITIES:
Accounts payable-affiliates	1	1
Accrued expenses and other payables	16,232	16,887
Total current liabilities	16,233	16,888
LONG-TERM DEBT, net of debt issuance costs and current maturities	989,171	1,011,365
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS	58,742
EQUITY :
Partners' equity	1,926,219	1,656,358
Total equity	1,926,219	1,656,358
Total liabilities, convertible preferred units and equity	2,990,365
Liabilities and Equity		2,684,611
Reportable Entity | Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	12,179	784	4,547	9,757
Accounts receivable - trade, net of allowance for doubtful accounts	585,720	516,362
Accounts receivable-affiliates	3,540	15,625
Inventories	519,795	367,250
Prepaid expenses and other current assets	109,969	94,426
Total current assets	1,231,203	994,447
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,653,011	1,568,488
GOODWILL	1,448,661	1,313,364
INTANGIBLE ASSETS, net of accumulated amortization	1,166,439	1,146,355
INVESTMENTS IN UNCONSOLIDATED ENTITIES	190,662	219,550
NET INTERCOMPANY RECEIVABLES (PAYABLES)	(1,279,908)	(1,402,360)
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	96,577	42,227
LOAN RECEIVABLE-AFFILIATE	1,700	22,262
OTHER NONCURRENT ASSETS	217,618	175,512
Total assets	4,725,963	4,079,845
CURRENT LIABILITIES:
Accounts payable-trade	510,535	417,707
Accounts payable-affiliates	6,054	7,190
Accrued expenses and other payables	164,918	196,596
Advance payments received from customers	87,094	55,737
Current maturities of long-term debt	7,252	7,109
Total current liabilities	775,853	684,339
LONG-TERM DEBT, net of debt issuance costs and current maturities	2,067,264	1,894,428
OTHER NONCURRENT LIABILITIES	193,213	246,695
CLASS A 10.75% CONVERTIBLE PREFERRED UNITS	0
EQUITY :
Partners' equity	1,690,096	1,254,384
Accumulated other comprehensive loss	(463)	(1)
Noncontrolling interests	0
Total equity	1,689,633	1,254,383
Total liabilities, convertible preferred units and equity	4,725,963
Liabilities and Equity		4,079,845
Reportable Entity | Non-Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	1,132	1,643	$ 2,464	$ 2,431
Accounts receivable - trade, net of allowance for doubtful accounts	6,354	4,652
Accounts receivable-affiliates	0	0
Inventories	545	556
Prepaid expenses and other current assets	949	1,433
Total current assets	8,980	8,284
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	102,405	81,084
GOODWILL	19,294	1,998
INTANGIBLE ASSETS, net of accumulated amortization	23,708	2,535
INVESTMENTS IN UNCONSOLIDATED ENTITIES	0	0
NET INTERCOMPANY RECEIVABLES (PAYABLES)	(10,708)	(2,119)
OTHER NONCURRENT ASSETS	121	527
Total assets	143,800	92,309
CURRENT LIABILITIES:
Accounts payable-trade	1,569	2,599
Accounts payable-affiliates	189	2
Accrued expenses and other payables	3,484	943
Advance payments received from customers	731	448
Current maturities of long-term debt	794	798
Total current liabilities	6,767	4,790
LONG-TERM DEBT, net of debt issuance costs and current maturities	6,573	7,044
OTHER NONCURRENT LIABILITIES	4,788	541
EQUITY :
Partners' equity	125,851	80,090
Accumulated other comprehensive loss	(179)	(156)
Total equity	125,672	79,934
Total liabilities, convertible preferred units and equity	143,800
Liabilities and Equity		92,309
Consolidating Adjustments
CURRENT ASSETS:
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	(1,786,210)	(1,296,610)
Total assets	(1,786,210)	(1,296,610)
EQUITY :
Partners' equity	(1,815,305)	(1,334,317)
Noncontrolling interests	29,095	37,707
Total equity	(1,786,210)	(1,296,610)
Total liabilities, convertible preferred units and equity	$ (1,786,210)
Liabilities and Equity		$ (1,296,610)

Condensed Consolidating Guara84

Condensed Consolidating Guarantor and Non-Guarantor Financial Information - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Consolidating Statement of Operations
REVENUES	$ 3,045,538	$ 3,193,195	$ 5,767,508	$ 6,731,664
COST OF SALES	2,928,730	3,005,826	5,495,170	6,328,377
OPERATING COSTS AND EXPENSES:
Operating	73,255	97,630	148,427	203,220
General and administrative	27,926	29,298	69,797	91,779
Depreciation and amortization	50,603	56,761	99,509	116,592
Loss (gain) on disposal or impairment of assets, net	852	1,291	(203,467)	1,712
Revaluation of liabilities	0	(15,909)	0	(27,104)
Operating (Loss) Income	(35,828)	18,298	158,072	17,088
OTHER INCOME (EXPENSE):
Equity in earnings (loss) of unconsolidated entities	53	2,432	447	11,150
Revaluation of investments	0	0	(14,365)	0
Interest expense	(33,442)	(31,571)	(63,880)	(62,373)
Gain on early extinguishment of liabilities	938	0	30,890	0
Other income, net	2,081	1,955	5,853	780
Income (loss) before income taxes	(66,198)	(8,886)	117,017	(33,355)
INCOME TAX BENEFIT (EXPENSE)	(460)	2,786	(922)	2,248
Net Loss (Income)	(66,658)	(6,100)	116,095	(31,107)
LESS: NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS	59	(3,497)	(5,774)	(7,847)
LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS	(8,668)	0	(12,052)	0
LESS: NET LOSS (INCOME) ALLOCATED TO GENERAL PARTNER	45	(16,185)	(158)	(31,559)
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	(75,222)	(25,782)	98,111	(70,513)
Reportable Entity | NGL Energy Partners LP (Parent)
OTHER INCOME (EXPENSE):
Interest expense	(16,364)	(17,913)	(32,690)	(35,714)
Gain on early extinguishment of liabilities			8,614
Income (loss) before income taxes	(16,364)	(17,913)	(24,076)	(35,714)
EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES	(50,235)	8,316	134,397	(3,240)
Net Loss (Income)	(66,599)	(9,597)	110,321	(38,954)
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	(66,599)	(9,597)	110,321	(38,954)
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	3,034,053	3,153,370	5,749,034	6,650,251
COST OF SALES	2,928,036	3,009,777	5,493,864	6,333,438
OPERATING COSTS AND EXPENSES:
Operating	68,750	75,023	139,631	160,323
General and administrative	27,686	24,538	69,312	81,208
Depreciation and amortization	47,740	45,006	94,049	90,545
Loss (gain) on disposal or impairment of assets, net	896	1,294	(203,443)	1,715
Revaluation of liabilities		(15,909)		(27,104)
Operating (Loss) Income	(39,055)	13,641	155,621	10,126
OTHER INCOME (EXPENSE):
Equity in earnings (loss) of unconsolidated entities	53	(23)	447	2,872
Revaluation of investments			(14,365)
Interest expense	(16,870)	(11,351)	(30,898)	(22,344)
Gain on early extinguishment of liabilities	938		22,276
Other income, net	2,154	1,916	5,990	691
Income (loss) before income taxes	(52,780)	4,183	139,071	(8,655)
INCOME TAX BENEFIT (EXPENSE)	(460)	2,793	(922)	2,286
EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES	3,005	1,340	(3,752)	3,129
Net Loss (Income)	(50,235)	8,316	134,397	(3,240)
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	(50,235)	8,316	134,397	(3,240)
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	12,118	49,442	19,469	100,621
COST OF SALES	1,327	5,610	2,301	14,022
OPERATING COSTS AND EXPENSES:
Operating	4,505	22,663	8,796	43,022
General and administrative	240	4,760	485	10,571
Depreciation and amortization	2,863	11,755	5,460	26,047
Loss (gain) on disposal or impairment of assets, net	(44)	(3)	(24)	(3)
Operating (Loss) Income	3,227	4,657	2,451	6,962
OTHER INCOME (EXPENSE):
Equity in earnings (loss) of unconsolidated entities	0	2,455	0	8,278
Interest expense	(291)	(2,381)	(453)	(4,463)
Other income, net	10	113	24	237
Income (loss) before income taxes	2,946	4,844	2,022	11,014
INCOME TAX BENEFIT (EXPENSE)	0	(7)	0	(38)
Net Loss (Income)	2,946	4,837	2,022	10,976
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	2,946	4,837	2,022	10,976
Consolidating Adjustments
Condensed Consolidating Statement of Operations
REVENUES	(633)	(9,617)	(995)	(19,208)
COST OF SALES	(633)	(9,561)	(995)	(19,083)
OPERATING COSTS AND EXPENSES:
Operating	0	(56)	0	(125)
OTHER INCOME (EXPENSE):
Interest expense	83	74	161	148
Other income, net	(83)	(74)	(161)	(148)
EQUITY IN NET (LOSS) INCOME OF CONSOLIDATED SUBSIDIARIES	47,230	(9,656)	(130,645)	111
Net Loss (Income)	47,230	(9,656)	(130,645)	111
LESS: NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS	59	(3,497)	(5,774)	(7,847)
LESS: DISTRIBUTIONS TO PREFERRED UNITHOLDERS	(8,668)		(12,052)
LESS: NET LOSS (INCOME) ALLOCATED TO GENERAL PARTNER	45	(16,185)	(158)	(31,559)
NET (LOSS) INCOME ALLOCATED TO COMMON UNITHOLDERS	$ 38,666	$ (29,338)	$ (148,629)	$ (39,295)

Condensed Consolidating Guara85

Condensed Consolidating Guarantor and Non-Guarantor Financial Information - Condensed Consolidating Statements of Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Consolidating Statement of Comprehensive Income (Loss)
Net (loss) income	$ (66,658)	$ (6,100)	$ 116,095	$ (31,107)
Other comprehensive loss	(333)	(19)	(485)	(27)
Comprehensive income (loss)	(66,991)	(6,119)	115,610	(31,134)
Reportable Entity | NGL Energy Partners LP (Parent)
Condensed Consolidating Statement of Comprehensive Income (Loss)
Net (loss) income	(66,599)	(9,597)	110,321	(38,954)
Comprehensive income (loss)	(66,599)	(9,597)	110,321	(38,954)
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statement of Comprehensive Income (Loss)
Net (loss) income	(50,235)	8,316	134,397	(3,240)
Other comprehensive loss	(333)	0	(475)	0
Comprehensive income (loss)	(50,568)	8,316	133,922	(3,240)
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statement of Comprehensive Income (Loss)
Net (loss) income	2,946	4,837	2,022	10,976
Other comprehensive loss	0	(19)	(10)	(27)
Comprehensive income (loss)	2,946	4,818	2,012	10,949
Consolidating Adjustments
Condensed Consolidating Statement of Comprehensive Income (Loss)
Net (loss) income	47,230	(9,656)	(130,645)	111
Comprehensive income (loss)	$ 47,230	$ (9,656)	$ (130,645)	$ 111

Condensed Consolidating Guara86

Condensed Consolidating Guarantor and Non-Guarantor Financial Information - Condensed Consolidating Statements Of Cash Flows (Details) - USD ($) $ in Thousands	6 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities	$ (56,399)	$ 174,095
INVESTING ACTIVITIES:
Capital expenditures	(159,680)	(222,276)
Purchases of pipeline capacity allocations	(41,953)	0
Acquisitions of businesses, including acquired working capital, net of cash acquired	(113,297)	(150,546)
Cash flows from commodity derivatives	(25,015)	43,032
Proceeds from sales of assets	396	3,567
Proceeds from sale of TLP common units	112,370	0
Investments in unconsolidated entities	0	(6,926)
Distributions of capital from unconsolidated entities	5,233	8,207
Loan for natural gas liquids facility	0	(3,913)
Payments on loan for natural gas liquids facility	4,324	3,546
Loan to affiliate	(1,700)	(15,621)
Payments on loan to affiliate	655	0
Payment to terminate contract	(16,875)	0
Net cash used in investing activities	(235,542)	(340,930)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	770,000	1,354,700
Payments on revolving credit facilities	(595,500)	(1,006,600)
Repurchases of senior notes	(15,129)	0
Payments on other long-term debt	(4,423)	(2,344)
Debt issuance costs	(320)	(1,380)
Contributions from partners	(442)	45
Contributions from noncontrolling interest owners	966	6,613
Distributions to partners	(83,707)	(154,824)
Distributions to noncontrolling interest owners	(2,750)	(17,780)
Taxes paid on behalf of equity incentive plan participants	0	(19,083)
Proceeds from sale of convertible preferred units and warrants, net of offering costs	235,018	0
Proceeds from sale of common units, net of offering costs	9,383	0
Payments for the early extinguishment of liabilities	(25,884)	0
Common unit repurchases	0	(3,650)
Other	(20)	(112)
Net cash provided by financing activities	287,192	155,585
Net decrease in cash and cash equivalents	(4,749)	(11,250)
Cash and cash equivalents, beginning of period	28,176	41,303
Cash and cash equivalents, end of period	23,427	30,053
Reportable Entity | NGL Energy Partners LP (Parent)
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities	(31,541)	(34,469)
FINANCING ACTIVITIES:
Repurchases of senior notes	(15,129)
Debt issuance costs	(255)	49
Contributions from partners	(442)	45
Distributions to partners	(83,707)	(154,824)
Proceeds from sale of convertible preferred units and warrants, net of offering costs	235,018
Proceeds from sale of common units, net of offering costs	9,383
Net changes in advances with consolidated entities	(128,960)	186,776
Common unit repurchases		(3,650)
Net cash provided by financing activities	15,908	28,396
Net decrease in cash and cash equivalents	(15,633)	(6,073)
Cash and cash equivalents, beginning of period	25,749	29,115
Cash and cash equivalents, end of period	10,116	23,042
Reportable Entity | Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities	(12,751)	173,058
INVESTING ACTIVITIES:
Capital expenditures	(158,333)	(184,680)
Purchases of pipeline capacity allocations	(41,953)
Acquisitions of businesses, including acquired working capital, net of cash acquired	(113,297)	(150,546)
Cash flows from commodity derivatives	(25,015)	43,032
Proceeds from sales of assets	379	3,565
Proceeds from sale of TLP common units	112,370
Investments in unconsolidated entities		(2,700)
Distributions of capital from unconsolidated entities	5,233	5,652
Loan for natural gas liquids facility		(3,913)
Payments on loan for natural gas liquids facility	4,324	3,546
Loan to affiliate	(1,700)	(15,621)
Payments on loan to affiliate	655
Payment to terminate contract	(16,875)
Net cash used in investing activities	(234,212)	(301,665)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	770,000	1,311,500
Payments on revolving credit facilities	(595,500)	(963,000)
Repurchases of senior notes	0
Payments on other long-term debt	(4,080)	(2,274)
Debt issuance costs	(65)	(180)
Contributions from partners	0	0
Contributions from noncontrolling interest owners	0	0
Distributions to partners	0	0
Distributions to noncontrolling interest owners	0	0
Taxes paid on behalf of equity incentive plan participants		(19,083)
Proceeds from sale of convertible preferred units and warrants, net of offering costs	0
Payments for the early extinguishment of liabilities	(25,884)
Net changes in advances with consolidated entities	113,907	(203,533)
Other	(20)	(33)
Net cash provided by financing activities	258,358	123,397
Net decrease in cash and cash equivalents	11,395	(5,210)
Cash and cash equivalents, beginning of period	784	9,757
Cash and cash equivalents, end of period	12,179	4,547
Reportable Entity | Non-Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash (used in) provided by operating activities	(12,107)	35,506
INVESTING ACTIVITIES:
Capital expenditures	(1,347)	(37,596)
Acquisitions of businesses, including acquired working capital, net of cash acquired	0	0
Proceeds from sales of assets	17	2
Investments in unconsolidated entities		(4,226)
Distributions of capital from unconsolidated entities	0	2,555
Payments on loan for natural gas liquids facility		0
Loan to affiliate		0
Net cash used in investing activities	(1,330)	(39,265)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	0	43,200
Payments on revolving credit facilities	0	(43,600)
Payments on other long-term debt	(343)	(70)
Debt issuance costs	0	(1,249)
Contributions from noncontrolling interest owners	966	6,613
Distributions to noncontrolling interest owners	(2,750)	(17,780)
Net changes in advances with consolidated entities	15,053	16,757
Other	0	(79)
Net cash provided by financing activities	12,926	3,792
Net decrease in cash and cash equivalents	(511)	33
Cash and cash equivalents, beginning of period	1,643	2,431
Cash and cash equivalents, end of period	$ 1,132	$ 2,464