High Sierra Compression S-4/A 24 Dec 14 Registration of securities issued in business combination transactions (amended) Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Sep. 30, 2014
Document and Entity Information
Entity Registrant Name	NGL Energy Partners LP
Entity Central Index Key	1504461
Document Type	S-4/A
Pre-Effective Amendment Number	2
Document Period End Date	30-Sep-14
Amendment Flag	FALSE
Entity Filer Category	Large Accelerated Filer

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$11,823	$10,440	$5,528	$11,561	$7,832	$16,337
Accounts receivable - trade, net of allowance for doubtful accounts of $2,816 and $2,822, respectively	1,433,117	900,904		562,757
Accounts receivable - affiliates	41,706	7,445		22,883
Inventories	941,589	310,160		126,895
Prepaid expenses and other current assets	156,818	80,350		37,891
Total current assets	2,585,053	1,309,299		761,987
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $153,057 and $109,564, respectively	1,433,313	829,346		526,437
GOODWILL	1,170,490	1,107,006		555,220	167,245	8,568
INTANGIBLE ASSETS, net of accumulated amortization of $166,484 and $116,728, respectively	838,088	714,956		441,432
INVESTMENTS IN UNCONSOLIDATED ENTITIES	482,644	189,821
OTHER NONCURRENT ASSETS	42,091	16,795		6,542
Total assets	6,551,679	4,167,223		2,291,618
CURRENT LIABILITIES:
Accounts payable - trade	1,345,024	740,211		536,055
Accounts payable - affiliates	85,307	76,846		6,900
Accrued expenses and other payables	218,482	141,690		85,606
Advance payments received from customers	106,105	29,965		22,372
Current maturities of long-term debt	5,062	7,080		8,626
Total current liabilities	1,759,980	995,792		659,559
LONG-TERM DEBT, net of current maturities	2,437,351	1,629,834		740,436
OTHER NONCURRENT LIABILITIES	39,518	9,744		2,205
COMMITMENTS AND CONTINGENCIES
EQUITY, per accompanying statement:
General partner, representing a 0.1% interest, 79,420 and 53,676 notional units at March 31, 2014 and 2013, respectively	-39,690	-45,287		-50,497
Limited partners, representing a 99.9% interest -
Accumulated other comprehensive income (loss)	-73	-236		24
Noncontrolling interests	568,770	5,274		5,740
Total equity	2,314,830	1,531,853		889,418	405,329	47,353
Total liabilities and equity	6,551,679	4,167,223		2,291,618
Common Units
Limited partners, representing a 99.9% interest -
Limited partners, representing a 99.9% interest -	1,785,823	1,570,074		920,998
Subordinated Units
Limited partners, representing a 99.9% interest -
Limited partners, representing a 99.9% interest -		$2,028		$13,153

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	0 Months Ended	6 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	17-May-11	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
Accounts receivable - trade, allowance for doubtful accounts (in dollars)		$2,816	$2,822	$1,760
PROPERTY, PLANT AND EQUIPMENT, accumulated depreciation (in dollars)		153,057	109,564	50,127
INTANGIBLE ASSETS, accumulated amortization (in dollars)		$166,484	$116,728	$44,155
General partner, interest (as a percent)	0.10%	0.10%	0.10%	0.10%
General partner, notional units outstanding		88,634	79,420	53,676
Limited partners, interest (as a percent)		99.90%	99.90%	99.90%
Common Units
Units issued		88,545,764	73,421,309	47,703,313
Units outstanding	8,864,222	88,545,764	73,421,309	47,703,313
Subordinated Units
Units issued			5,919,346	5,919,346
Units outstanding	5,919,346		5,919,346	5,919,346

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014
REVENUES:
Crude oil logistics	$4,558,545
Water solutions	143,100
Liquids Revenue	2,650,425
Retail propane	551,815
Refined products	1,180,895
Renewables	176,781
Other	437,713
Total Revenues	9,699,274
COST OF SALES:
Crude oil logistics	4,477,397
Water solutions	11,738
Liquids	2,518,099
Retail propane	354,676
Refined products	1,172,754
Renewables	171,422
Other	426,613
Total Cost of Sales	9,132,699
OPERATING COSTS AND EXPENSES:
Operating	259,396
General and administrative	79,860
Depreciation and amortization	120,754
Operating Income (Loss)	106,565
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	1,898
Interest expense	-58,854
Other, net	86
Loss before Income Taxes	49,695
INCOME TAX PROVISION	-937
Net Loss	48,758
NET INCOME ALLOCATED TO GENERAL PARTNER	-14,148
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-1,103
NET LOSS ALLOCATED TO LIMITED PARTNERS	33,507
Common Units
OTHER INCOME (EXPENSE):
NET LOSS ALLOCATED TO LIMITED PARTNERS	31,614
BASIC AND DILUTED LOSS PER COMMON UNIT (in dollars per unit)	$0.51
BASIC AND DILUTED WEIGHTED AVERAGE UNITS OUTSTANDING:
COMMON UNITS OUTSTANDING (In shares)	61,970,471
Subordinated Units
OTHER INCOME (EXPENSE):
NET LOSS ALLOCATED TO LIMITED PARTNERS	$1,893
BASIC AND DILUTED LOSS PER COMMON UNIT (in dollars per unit)	$0.32
BASIC AND DILUTED WEIGHTED AVERAGE UNITS OUTSTANDING:
COMMON UNITS OUTSTANDING (In shares)	5,919,346

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Condensed Consolidated Statements of Comprehensive Income (Loss)
Net income	($15,879)	$43,146	$24,052	($932)	($17,508)	$22,341	$40,477	$10,082	($24,710)	($55,789)	($18,440)	$48,758	$48,190	$7,864
Other comprehensive income (loss)	-22			-5						163	-30	-260	-7	-25
Comprehensive loss	($15,901)			($937)						($55,626)	($18,470)	$48,498	$48,183	$7,839

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Equity (USD $)	Total	Common Units	Accumulated Other Comprehensive Income	Noncontrolling Interest	General Partner	Limited Partners	Limited Partners
In Thousands, except Share data, unless otherwise specified	USD ($)		USD ($)	USD ($)	USD ($)	Common Units	Subordinated Units
						USD ($)	USD ($)
BALANCES at Mar. 31, 2011	$47,353		$56		$72	$47,225
BALANCES (in units) at Mar. 31, 2011						10,933,568
Increase (Decrease) in Partnership Capital
Distributions to partners prior to initial public offering	-3,850				-4	-3,846
Conversion of common units to subordinated units						-23,485	23,485
Conversion of subordinated units to common units (in units)						-5,919,346	5,919,346
Sales of units, net of issuance costs	75,289					75,289
Sales of units, net of issuance costs (in units)						4,025,000
Repurchase of common units	-3,418					-3,418
Repurchase of common units (in units)						-175,000
Contributions	826			440	386
Units issued in business combinations, net of issuance costs	296,500					296,500
Units issued in business combinations, net of issuance costs (in units)						14,432,031
Net loss	7,864			-12	8	6,472	1,396
Distribution to partners subsequent to initial public offering	-15,210				-20	-10,133	-5,057
Other comprehensive loss	-25		-25
BALANCES at Mar. 31, 2012	405,329		31	428	442	384,604	19,824
BALANCES (in units) at Mar. 31, 2012						23,296,253	5,919,346
Increase (Decrease) in Partnership Capital
Distributions	-71,682			-74	-1,778	-59,841	-9,989
Contributions	913			403	510
Units issued in business combinations, net of issuance costs	503,018			4,733	-52,588	550,873
Units issued in business combinations, net of issuance costs (in units)						24,250,258
Equity issued pursuant to incentive compensation plan	3,657					3,657
Equity issued pursuant to incentive compensation plan (in units)						156,802
Net loss	48,190			250	2,917	41,705	3,318
Other comprehensive loss	-7		-7
BALANCES at Mar. 31, 2013	889,418		24	5,740	-50,497	920,998	13,153
BALANCES (in units) at Mar. 31, 2013						47,703,313	5,919,346
Increase (Decrease) in Partnership Capital
Sales of units, net of issuance costs	650,155					650,155
Sales of units, net of issuance costs (in units)						22,560,848
Distributions	-145,930			-840	-9,703	-123,467	-11,920
Contributions	2,825			2,060	765
Units issued in business combinations, net of issuance costs	80,591					80,591
Units issued in business combinations, net of issuance costs (in units)						2,860,879
Equity issued pursuant to incentive compensation plan	9,085					9,085
Equity issued pursuant to incentive compensation plan (in units)						296,269
Disposal of noncontrolling interest	-2,789			-2,789
Net loss	48,758			1,103	14,148	32,712	795
Other comprehensive loss	-260		-260
BALANCES at Mar. 31, 2014	1,531,853		-236	5,274	-45,287	1,570,074	2,028
BALANCES (in units) at Mar. 31, 2014						73,421,309	5,919,346
Increase (Decrease) in Partnership Capital
Conversion of common units to subordinated units						-8,733	8,733
Conversion of subordinated units to common units (in units)						5,919,346	-5,919,346
Sales of units, net of issuance costs	370,446					370,446
Sales of units, net of issuance costs (in units)						8,767,100
Distributions	-119,662			-8,654	-15,235	-89,025	-6,748
Equity issued pursuant to incentive compensation plan	18,684					18,684
Equity issued pursuant to incentive compensation plan (in units)						438,009
Net loss	-55,789			3,410	20,437	-75,623	-4,013
Other comprehensive loss	163		163
BALANCES at Sep. 30, 2014	$2,314,830		($73)	$568,770	($39,690)	$1,785,823
BALANCES (in units) at Sep. 30, 2014						88,545,764

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
OPERATING ACTIVITIES:
Net income	$48,758	$48,190	$7,864
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization, including debt issuance cost amortization	132,653	77,513	17,188
Loss on early extinguishment of debt		5,769
Non-cash equity-based compensation expense	14,054	8,670
Loss (gain) on disposal or impairment of assets	3,597	187	-71
Provision for doubtful accounts	2,172	1,315	1,049
Commodity derivative (gain) loss	43,655	4,376	-5,974
Earnings of unconsolidated entities	-1,898
Other	312	375	403
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable - trade	21,388	2,562	-20,179
Accounts receivable - affiliates	18,002	-12,877	193
Inventories	-73,321	18,433	30,268
Prepaid expenses and other current assets	18,900	22,585	14,344
Accounts payable - trade	-146,152	-16,913	35,747
Accounts payable - affiliates	67,361	-6,813	4,549
Accrued expenses and other payables	-61,171	-9,689	366
Advance payments received from customers	-3,074	-11,049	4,582
Net cash used in operating activities	85,236	132,634	90,329
INVESTING ACTIVITIES:
Purchases of long-lived assets	-165,148	-72,475	-7,544
Acquisitions of businesses, including acquired working capital, net of cash acquired	-1,268,810	-490,805	-297,401
Cash flows from commodity derivatives	-35,956	11,579	6,464
Proceeds from sales of assets	24,660	5,080	1,238
Investments in unconsolidated entities	-11,515
Distributions of capital from unconsolidated entities	1,591
Other	-195		346
Net cash used in investing activities	-1,455,373	-546,621	-296,897
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	2,545,500	1,227,975	478,900
Payments on revolving credit facilities	-2,101,000	-964,475	-329,900
Issuances of notes	450,000	250,000
Proceeds from borrowings on other long-term debt	880	653
Payments on other long-term debt	-8,819	-4,837	-1,278
Debt issuance costs	-24,595	-20,189	-2,380
Contributions	2,825	913	440
Distributions	-145,930	-71,682	-19,060
Proceeds from sale of common units, net of offering costs	650,155	-642	74,759
Repurchase of common units			-3,418
Net cash provided by financing activities	1,369,016	417,716	198,063
Net increase (decrease) in cash and cash equivalents	-1,121	3,729	-8,505
Cash and cash equivalents, beginning of period	11,561	7,832	16,337
Cash and cash equivalents, end of period	$10,440	$11,561	$7,832

Nature_of_Operations_and_Organ

Nature of Operations and Organization	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Organization and Operations
Nature of Operations and Organization	Note 1 — Organization and Operations	Note 1 — Nature of Operations and Organization
	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, 2014, our operations include:	NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership formed in September 2010 by several investors (“IEP Parties”). NGL Energy Holdings LLC serves as our general partner. At March 31, 2014, our operations include:
	·         Our crude oil logistics segment, the assets of which include owned and leased crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased and owned railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics segment purchases crude oil from producers and transports it for resale at owned and leased pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.	·                  A crude oil logistics business, the assets of which include crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics business purchases crude oil from producers and transports it for resale at pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.
	·         Our water solutions segment, the assets of which include water treatment and disposal facilities. Our water solutions segment generates revenues from the treatment and disposal of wastewater generated from crude oil and natural gas production, and from the sale of recycled water and recovered hydrocarbons.	·                  A water solutions business, the assets of which include water treatment and disposal facilities, a fleet of water trucks, and frac tanks. Our water solutions business generates revenues from the gathering, transportation, treatment, and disposal of wastewater generated from crude oil and natural gas production operations, and from the sale of recycled water and recovered hydrocarbons.
	·         Our liquids segment, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids segment purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, petrochemical plants, and other participants in the wholesale markets.	·                  Our liquids business, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids business purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, and other participants in the wholesale markets.
	·         Our retail propane segment, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.	·                  Our retail propane business, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.
	·         Our refined products and renewables segment, which conducts gasoline, diesel, ethanol, and biodiesel marketing operations. We also own the 2.0% general partner interest and a 19.7% limited partner interest in TransMontaigne Partners L.P. (“TLP”), which conducts refined products terminaling operations. TLP also owns a 42.5% interest in Battleground Oil Specialty Terminal Company LLC (“BOSTCO”) and a 50% interest in Frontera Brownsville LLC (“Frontera”), which are entities that own refined products storage facilities.	We also operate a refined products marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities. We also operate a renewables business, which purchases ethanol primarily at production facilities and transports the ethanol for sale at various locations to refiners and blenders, and purchases biodiesel from production facilities in the Midwest and in Houston, Texas, and transports the product using leased railcars for sale to refiners and blenders. These businesses were acquired in our December 2013 acquisition of Gavilon, LLC (“Gavilon Energy”).
		Initial Public Offering
		On May 17, 2011, we completed our initial public offering (“IPO”). We sold a total of 4,025,000 common units in our IPO at $21.00 per unit. Our proceeds from the sale of 3,850,000 common units of $71.9 million, net of total offering costs of $9.0 million, were used to repay advances under our acquisition credit facility and for general partnership purposes. Proceeds from the sale of 175,000 common units ($3.4 million) from the underwriters’ exercise of their option to purchase additional common units from us were used to redeem 175,000 of the common units outstanding prior to our IPO. Upon the completion of our IPO and the underwriters’ exercise in full of their option to purchase additional common units from us and the redemption, we had outstanding 8,864,222 common units, 5,919,346 subordinated units, a 0.1% general partner interest, and incentive distribution rights (“IDRs”).
		Acquisitions Subsequent to Initial Public Offering
		Subsequent to our IPO, we significantly expanded our operations through a number of business combinations, including the following, among others:
		·                  In October 2011, we completed a business combination with E. Osterman Propane, Inc., its affiliated companies, and members of the Osterman family, whereby we acquired retail propane operations in the northeastern United States.
		·                  In November 2011, we completed a business combination with SemStream, L.P. (“SemStream”), whereby we acquired SemStream’s wholesale natural gas liquids supply and marketing operations and its 12 natural gas liquids terminals.
		·                  In January 2012, we completed a business combination with seven companies associated with Pacer Propane Holding, L.P., whereby we acquired retail propane operations, primarily in the western United States.
		·                  In February 2012, we completed a business combination with North American Propane, Inc., whereby we acquired retail propane and distillate operations in the northeastern United States.
		·                  In May 2012, we acquired the retail propane and distillate operations of Downeast Energy Corp (“Downeast”). These operations are primarily in the northeastern United States.
		·                  In June 2012, we completed a business combination with High Sierra Energy, LP and High Sierra Energy GP, LLC (collectively, “High Sierra”), whereby we acquired all of the ownership interests in High Sierra. High Sierra’s businesses include crude oil gathering, transportation and marketing; water treatment, disposal, and transportation; and natural gas liquids transportation and marketing.
		·                  In November 2012, we completed a business combination whereby we acquired Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”). The business of Pecos consists primarily of crude oil purchasing and logistics operations in Texas and New Mexico.
		·                  In December 2012, we completed a business combination whereby we acquired all of the membership interests in Third Coast Towing LLC (“Third Coast”). The business of Third Coast consists primarily of transporting crude oil via barge.
		·                  In July 2013, we completed a business combination whereby we acquired the assets of Crescent Terminals, LLC and the ownership interests in Cierra Marine, LP and its affiliated companies (collectively, “Crescent”), whereby we acquired four towboats, seven crude oil barges, and a crude oil terminal in South Texas.
		·                  In July 2013, we completed a business combination with High Roller Wells Big Lake SWD No. 1, Ltd. (“Big Lake”), whereby we acquired a water disposal facility in West Texas. We also entered into a development agreement that provides us the option to purchase disposal facilities that may be developed in the future. During March 2014, we purchased one additional facility under this agreement.
		·                  In August 2013, we completed a business combination whereby we acquired seven entities affiliated with Oilfield Water Lines LP (collectively, “OWL”). The businesses of OWL include water disposal operations and a water transportation business in Texas.
		·                  In September 2013, we completed a business combination with Coastal Plains Disposal #1, LLC (“Coastal”), in which we acquired the ownership interests in water disposal facilities in Texas and the right to purchase one additional facility, which we exercised in March 2014.
		·                  In December 2013, we acquired the ownership interests in Gavilon Energy. The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana and a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”), which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma. This pipeline became operational in February 2014. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids.

Significant_Accounting_Policie

Significant Accounting Policies	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Significant Accounting Policies
Significant Accounting Policies	Note 2 — Significant Accounting Policies									Note 2 — Significant Accounting Policies
	Basis of Presentation									Basis of Presentation
	The unaudited condensed consolidated financial statements as of and for the three months and six months ended September 30, 2014 and 2013 include our accounts and those of our controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All significant intercompany transactions and account balances have been eliminated in consolidation. The unaudited condensed consolidated balance sheet at March 31, 2014 is derived from audited financial statements. We have made certain reclassifications to prior period financial statements to conform to classification methods used in fiscal year 2015. These reclassifications had no impact on previously reported amounts of equity or net income.									Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of the Partnership and its controlled subsidiaries. All significant intercompany transactions and account balances have been eliminated in consolidation.
	The accompanying unaudited condensed consolidated financial statements have been 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. 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 of only normal recurring items, unless otherwise disclosed herein. Accordingly, the unaudited condensed consolidated financial statements do not include all the 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 not misleading. These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the fiscal year ended March 31, 2014 included in our Annual Report on Form 10-K (the “Annual Report”). Due to the seasonal nature of our natural gas liquids operations and other factors, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.									We have made certain reclassifications to the prior period financial statements to conform with classification methods used in fiscal 2014. These reclassifications had no impact on previously-reported amounts of equity or net income. In addition, certain balances at March 31, 2013 were adjusted to reflect the final acquisition accounting for certain business combinations.
	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 reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period. Actual results could differ from those estimates.									The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period.
	Significant Accounting Policies									Critical estimates we make in the preparation of our consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations; the collectability of accounts receivable; the recoverability of inventories; useful lives and recoverability of property, plant and equipment and amortizable intangible assets; the impairment of goodwill; the fair value of derivative financial investments; and accruals for various commitments and contingencies, among others. Although we believe these estimates are reasonable, actual results could differ from those estimates.
	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
	Revenue Recognition									We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.
	We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, transportation, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Pursuant to terminaling services agreements with certain of our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Such measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.									We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our condensed consolidated statements of operations.									·                  Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.
	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 concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.									·                  Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at March 31, 2014 and 2013 (see Note 12). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.
	Fair Value Measurements									·                  Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at March 31, 2014 or 2013.
	We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.									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 the fair value measurement requires judgment, considering factors specific to the asset or liability.
	We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:									Derivative Financial Instruments
	·         Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.									We record our derivative financial instrument contracts at fair value in the consolidated balance sheets, with changes in the fair value of our commodity derivative instruments included in our consolidated statements of operations in cost of sales. Contracts that qualify for the normal purchase or sale exemption and are designated as such are not accounted for as derivatives at market value and, accordingly, are recorded when the delivery occurs.
	·         Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at September 30, 2014 and March 31, 2014 (see Note 11). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.									We have not designated any financial instruments as hedges for accounting purposes. All mark-to-market gains and losses on commodity derivative instruments that do not qualify as normal purchases or sales, whether cash transactions or non-cash mark-to-market adjustments, are reported within cost of sales in the consolidated statements of operations, regardless of whether the contract is physically or financially settled.
	·         Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at September 30, 2014 or March 31, 2014.									We utilize various commodity derivative financial instrument contracts to help reduce our exposure to variability in future commodity prices. We do not enter 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 the 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 market risk and credit risk. Market risk is the risk that the value of the portfolio will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from non-performance by suppliers, customers, or financial counterparties to a contract. We take an active role in managing and controlling market and credit risk and have established control procedures that we review on an ongoing basis. We monitor market risk through a variety of techniques and attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures.
	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 the fair value measurement requires judgment, considering factors specific to the asset or liability.									Revenue Recognition
	Supplemental Cash Flow Information									We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for the wastewater disposal business are recognized upon receipt of the wastewater at our disposal facilities.
	Supplemental cash flow information is as follows:									We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in the consolidated statements of operations.
		Three Months Ended				Six Months Ended				We enter into certain contracts whereby we agree to purchase product from a counterparty and to sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.
		September 30,				September 30,
		2014		2013		2014		2013		Cost of Sales
		(in thousands)
	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	10,445	$	8,423	$	36,429	$	16,908	We include in cost of sales all costs we incur to acquire products, including the costs of purchasing, terminaling, and transporting inventory prior to delivery to our customers. Cost of sales does not include any depreciation of our property, plant and equipment. Cost of sales does include amortization of certain contract-based intangible assets of $6.2 million, $5.3 million, and $0.8 million during the years ended March 31, 2014, 2013, and 2012, respectively.
	Income taxes paid	$	1,241	$	369	$	2,246	$	650
										Depreciation and Amortization
	Value of common units issued in business combinations	$	—	$	80,619	$	—	$	80,619
										Depreciation and amortization in the consolidated statements of operations includes all depreciation of our property, plant and equipment and amortization of intangible assets other than debt issuance costs, for which the amortization is recorded to interest expense, and certain contract-based intangible assets, for which the amortization is recorded to cost of sales.
	Cash flows from settlements of commodity derivative instruments are classified as cash flows from investing activities in the condensed consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in the reconciliation of net loss to net cash used in operating activities.
										Cash and Cash Equivalents
	Inventories
										Cash and cash equivalents include cash on hand, demand and time deposits, and funds invested in highly liquid instruments with maturities of three months or less at the date of purchase. At times, certain account balances may exceed federally insured limits.
	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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
										Supplemental cash flow information is as follows:
	Inventories consist of the following:
											Year Ended March 31,
		September 30,		March 31,							2014			2013			2012
		2014		2014							(in thousands)
		(in thousands)								Interest paid, exclusive of debt issuance costs and letter of credit fees	$	31,827		$	27,384		$	4,966
	Crude oil	$	136,722	$	156,473					Income taxes paid	$	1,639		$	1,027		$	430
	Natural gas liquids —
	Propane	207,694		85,159						Cash flows from commodity derivative instruments are classified as cash flows from investing activities in the consolidated statements of cash flows.
	Butane	84,822		15,106
	Other	27,091		3,945						Accounts Receivable and Concentration of Credit Risk
	Refined products —
	Gasoline	219,111		15,597						We operate in the United States and Canada. We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions. The allowance for doubtful accounts is based on our assessment of the collectability of customer accounts, which assessment considers the overall creditworthiness of customers and any specific disputes. Accounts receivable are considered past due or delinquent based on contractual terms. We write off accounts receivable against the allowance for doubtful accounts when collection efforts have been exhausted.
	Diesel	214,567		7,298
	Other	3,675		314						We execute netting agreements with certain customers to mitigate our credit risk. Receivables and payables are reflected at a net balance to the extent a netting agreement is in place and we intend to settle on a net basis.
	Renewables	36,517		11,778
	Other	11,390		14,490						Our accounts receivable consist of the following:
	Total	$	941,589	$	310,160
											March 31, 2014						March 31, 2013
	Investments in Unconsolidated Entities																Gross
											Gross			Allowance for			Receivable			Allowance for
	In December 2013, as part of our acquisition of Gavilon, LLC (“Gavilon Energy”), we acquired a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”) and an 11% interest in a limited liability company that owns an ethanol production facility. In June 2014, we acquired an interest in a limited liability company that operates a water supply business. On July 1, 2014, as part of our acquisition of TransMontaigne Inc. (“TransMontaigne”), we acquired TLP, which owns a 42.5% interest in BOSTCO and a 50% interest in Frontera. We account for these investments 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 book value of the net assets of the investment entity.									Segment	Receivable			Doubtful Accounts			(Note 2)			Doubtful Accounts
											(in thousands)
	Our investments in unconsolidated entities consist of the following:									Crude oil logistics	$	411,090		$	105		$	360,589		$	11
										Water solutions	25,700			405			9,618			29
		September 30,		March 31,						Liquids	192,529			617			144,267			76
		2014		2014						Retail propane	75,606			1,667			49,233			1,644
		(in thousands)								Refined products	105,670			—			—			—
	Glass Mountain (1)	$	189,847	$	181,488					Renewables	54,466			—			—			—
Ethanol production facility	9,361		8,333						Other	38,665			28			810			—
Water supply company	15,026		—							$	903,726		$	2,822		$	564,517		$	1,760
BOSTCO (2)	244,092		—
Frontera	24,318		—						Changes in the allowance for doubtful accounts are as follows:
Total	$	482,644	$	189,821
										Year Ended March 31,
										2014			2013			2012
(1)     When we acquired Gavilon we recorded the investment in Glass Mountain at fair value. The fair value of our investment in Glass Mountain exceeds our share of the historical net book value of Glass Mountain’s net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.										(in thousands)
									Allowance for doubtful accounts, beginning of period	$	1,760		$	818		$	161
(2)     When we acquired TransMontaigne, we recorded the investment in BOSTCO at fair value. The fair value of our investment in BOSTCO exceeds our share of the historical net book value of BOSTCO’s net assets by approximately $24 million.									Provision for doubtful accounts	2,172			1,315			1,049
									Write off of uncollectible accounts	(1,110		)	(373		)	(392		)
Accrued Expenses and Other Payables									Allowance for doubtful accounts, end of period	$	2,822		$	1,760		$	818
Accrued expenses and other payables consist of the following:									For the year ended March 31, 2014, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. For the year ended March 31, 2013, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. At March 31, 2013, one customer of our crude oil logistics segment represented 10% of our consolidated accounts receivable balance.
	September 30,		March 31,						Inventories
	2014		2014
	(in thousands)								We value our inventory 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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
Accrued compensation and benefits	$	49,146	$	45,006
Derivative liabilities	39,023		42,214						Inventories consist of the following:
Product exchange liabilities	43,185		3,719
Accrued interest	23,945		18,668							March 31,
Income and other tax liabilities	38,255		13,421							2014			2013
Other	24,928		18,662							(in thousands)
Total	$	218,482	$	141,690					Crude oil	$	156,473		$	46,156
									Natural gas liquids —
Business Combination Measurement Period									Propane	85,159			45,428
									Butane and other	19,051			24,090
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 fair value of the assets acquired and liabilities assumed in a business combination. As described 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 described in Note 4, we made certain adjustments during the six months ended September 30, 2014 to our estimates of the acquisition-date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2014.									Refined products	23,209			—
									Renewables	11,778			—
Noncontrolling Interests									Other	14,490			11,221
										$	310,160		$	126,895
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’ share of these entities.
									Investments in Unconsolidated Entities
On July 1, 2014, as part of our acquisition of TransMontaigne, we acquired a 19.7% limited partner interest in TLP. We have attributed net earnings allocable to TLP’s limited partners to the controlling and noncontrolling interests based on the relative ownership interests in TLP as well as including certain adjustments related to our acquisition accounting. Net earnings allocable to TLP’s limited partners are net of the earnings allocable to TLP’s general partner interest. The earnings allocable to TLP’s general partner interest include the distributions of available cash (as defined by TLP’s partnership agreement) attributable to the period to TLP’s general partner interest and incentive distribution rights, net of adjustments for TLP’s general partner’s share of undistributed earnings. Undistributed earnings are allocated to TLP’s limited partners and TLP’s general partner interest based on their respective sharing of earnings or losses specified in TLP’s partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively.
									As part of the December 2013 acquisition of Gavilon Energy, we acquired a 50% interest in Glass Mountain and an 11% interest in a limited liability company that owns an ethanol production facility. We account for these investments under the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheet; instead, our ownership interests are reported within “Investments in Unconsolidated Entities” on our consolidated balance sheet. We record our share of any income or loss generated by these entities as an increase to our equity method investments, and record any distributions we receive from these entities as reductions to our equity method investments.
									Accrued Expenses and Other Payables
									Accrued expenses and other payables consist of the following:
										March 31,
													2013
										2014			(Note 4)
										(in thousands)
									Accrued compensation and benefits	$	45,006		$	27,252
									Derivative liabilities	42,214			12,701
									Income and other tax liabilities	13,421			22,659
									Product exchange liabilities	3,719			6,741
									Other	37,330			16,253
										$	141,690		$	85,606
									Property, Plant and Equipment
									We record property, plant and equipment at cost, less accumulated depreciation. Acquisitions and improvements are capitalized, and maintenance and repairs are expensed as incurred. As we dispose of assets, we remove the cost and related accumulated depreciation from the accounts, and any resulting gain or loss is included in other income. We compute depreciation expense using the straight-line method over the estimated useful lives of the assets (see Note 5).
									We evaluate the carrying value of our property, plant and equipment for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group.
									Intangible Assets
									Our intangible assets include contracts and arrangements acquired in business combinations, including lease agreements, customer relationships, covenants not to compete, and trade names. In addition, we capitalize certain debt issuance costs incurred in our long-term debt arrangements. We amortize our intangible assets on a straight-line basis over the assets’ estimated useful lives (see Note 7). We amortize debt issuance costs over the terms of the related debt on a method that approximates the effective interest method.
									We evaluate the carrying value of our amortizable intangible assets for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group. When we cease to use an acquired trade name, we test the trade name for impairment using the “relief from royalty” method and we begin amortizing the trade name over its estimated useful life as a defensive asset.
									Goodwill
									Goodwill represents the excess of cost over the fair value of net assets of acquired businesses. Business combinations are accounted for using the “acquisition method” (see Note 4). We expect that substantially all of our goodwill at March 31, 2014 is deductible for income tax purposes.
									Goodwill and intangible assets determined to have an indefinite useful life are not amortized, but instead are evaluated for impairment periodically. We evaluate goodwill and indefinite-lived intangible assets for impairment annually, or more often if events or circumstances indicate that the assets might be impaired. We perform the annual evaluation at January 1 of each year.
									To perform this assessment, we consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. If we conclude that it is more likely than not that the fair value of a reporting unit exceeds its carrying amount, we perform the following two-step goodwill impairment test:
									·                  In the first step of the goodwill impairment test, we compare the fair value of the reporting unit with its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its fair value, we perform the second step of the goodwill impairment test to measure the amount of impairment loss, if any.
									·                  In the second step of the goodwill impairment test, we compare the implied fair value of reporting unit goodwill with the carrying amount of that goodwill. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to that excess.
									Estimates and assumptions used to perform the impairment evaluation are inherently uncertain and can significantly affect the outcome of the analysis. The estimates and assumptions we used in the annual assessment for impairment of goodwill included market participant considerations and future forecasted operating results. Changes in operating results and other assumptions could materially affect these estimates. Based on our assessment of qualitative factors, we determined that the two-step impairment test was not required. Accordingly, we did not record any goodwill impairments during the years ended March 31, 2014, 2013, and 2012.
									Product Exchanges
									Quantities of products receivable or returnable under exchange agreements are reported within prepaid expenses and other current assets or within accrued expenses and other payables on the consolidated balance sheets. We estimate the value of product exchange assets and liabilities based on the weighted-average cost basis of the inventory we have delivered or will deliver on the exchange, plus or minus location differentials.
									Advance Payments Received from Customers
									We record customer advances on product purchases as a liability on the consolidated balance sheets.
									Noncontrolling Interests
									We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our consolidated statements of operations represents the other owners’ share of the net income (loss) of these entities.
									Water Facility Development Agreement
									In connection with one of our business combinations, we entered into a development agreement whereby we may acquire additional water disposal facilities in Texas. Under this agreement, the other party (the “Developer”) may develop facilities in a designated area. We then have the option to operate the facility for a period of up to 90 days, during which time we may elect to purchase the facility. If we elect to purchase the facility, the Developer may choose one of two options specified in the agreement for the calculation of the purchase price.
									During the period between which we have begun operating the facility and we have decided whether to purchase the facility, we are entitled to a fee for operating the facility, which is forfeitable if we elect not to purchase the facility. We recognize revenue for these operator fees once they cease to be forfeitable. When we elect to purchase a facility, we account for the transaction as a business combination.
									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 to obtain the information necessary to identify and measure the value of the assets acquired and liabilities assumed in a business combination. As described in Note 4, certain of our acquisitions during the year ended March 31, 2014 are still within this measurement period, and as a result, the acquisition-date fair values we have recorded for the acquired assets and assumed liabilities are subject to change.
									Also as described in Note 4, we made certain adjustments during the year ended March 31, 2014 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2013. We retrospectively adjusted the March 31, 2013 consolidated balance sheet for these adjustments. Due to the immateriality of these adjustments, we did not retrospectively adjust the consolidated statement of operations for the year ended March 31, 2013 for these measurement period adjustments.
									Discontinued Operations
									In April 2014, the Financial Accounting Standards Board issued an Accounting Standards Update that changes the criteria for reporting discontinued operations. Under the new standard, a disposal of part of an entity is not classified as a discontinued operation unless the disposal represents a strategic shift that will have a major effect on an entity’s operations and financial results. We adopted the new standard during the fiscal year ended March 31, 2014.
									As described in Note 14, during the year ended March 31, 2014, we sold our compressor leasing business and wound down our natural gas marketing business. These actions do not represent a strategic shift that had a major effect on our operations, and do not meet the criteria under the new accounting standard for these businesses to be reported as discontinued operations.

Earnings_per_Unit

Earnings per Unit	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Earnings Per Unit
Earnings per Unit	Note 3 — Earnings Per Unit													Note 3 — Earnings per Unit
	Our earnings per common unit were computed as follows:													Our earnings per common and subordinated unit were computed as follows:
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands, except unit and per unit amounts)
		(in thousands, except unit and per unit amounts)
	Net loss attributable to parent equity	$	(19,224	)	$	(941	)	$	(59,199	)	$	(18,574	)	Income attributable to parent equity	$	47,655		$	47,940		$	7,876
	Less: net income allocated to general partner (1)	(11,056		)	(2,451		)	(20,437		)	(4,139		)	Income allocated to general partner (1)	(14,148		)	(2,917		)	(8		)
	Net loss allocated to subordinated unitholders (2)	—			562			4,013			3,076			Income attributable to limited partners	$	33,507		$	45,023		$	7,868
	Net loss allocated to common unitholders	$	(30,280	)	$	(2,830	)	$	(75,623	)	$	(19,637	)
														Income allocated to:
	Weighted average common units outstanding	88,331,653			58,909,389			81,267,742			53,336,969			Common unitholders	$	31,614		$	39,517		$	4,859
														Subordinated unitholders	$	1,893		$	5,506		$	3,009
	Loss per common unit - basic and diluted	$	(0.34	)	$	(0.05	)	$	(0.93	)	$	(0.37	)
														Weighted average common units outstanding	61,970,471			41,353,574			15,169,983
														Weighted average subordinated units outstanding	5,919,346			5,919,346			5,175,384
	(1)     The net income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are described in Note 10.
	(2)     All outstanding subordinated units converted to common units in August 2014. Since the subordinated units did not share in the distribution of cash generated during the three months ended September 30, 2014, we did not allocate any earnings or loss during this period to the subordinated unitholders. During the three months ended June 30, 2014 and the six months ended September 30, 2013, 5,919,346 subordinated units were outstanding. The loss per subordinated unit was $(0.68) for the three months ended June 30, 2014, $(0.09) for the three months ended September 30, 2013, and $(0.52) for the six months ended September 30, 2013.													Income per common unit - basic and diluted	$	0.51		$	0.96		$	0.32
	The restricted units described in Note 10 were antidilutive during the three months and six months ended September 30, 2014 and 2013, but could impact earnings per unit in future periods.													Income per subordinated unit - basic and diluted	$	0.32		$	0.93		$	0.58
														(1)         The income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights (“IDRs”), which are described in Note 11.
														The restricted units described in Note 11 were antidilutive for the years ended March 31, 2014, 2013, and 2012.

Acquisitions

Acquisitions	6 Months Ended										12 Months Ended
	Sep. 30, 2014										Mar. 31, 2014
Acquisitions
Acquisitions	Note 4 — Acquisitions										Note 4 — Acquisitions
	Year Ending March 31, 2015										Year Ended March 31, 2014
	TransMontaigne Inc.										Gavilon Energy
	On July 1, 2014, we acquired TransMontaigne for $174.2 million of cash, net of cash acquired. As part of this transaction, we also purchased $380.4 million of inventory from the previous owner of TransMontaigne (including $346.9 million paid at closing and $33.5 million subsequently paid as the working capital settlement process progressed). The operations of TransMontaigne include the marketing of refined products and crude oil. As part of this transaction, we acquired the 2.0% general partner interest, the incentive distribution rights, and a 19.7% limited partner interest in TLP, and assumed certain terminaling service agreements with TLP from an affiliate of the previous owner of TransMontaigne. The acquisition agreement contemplates a post-closing adjustment to the purchase price for certain working capital items. We estimate that we will pay an additional $27.5 million once the working capital settlement process has been completed.										On December 2, 2013, we completed a business combination in which we acquired Gavilon Energy. We paid $832.4 million of cash, net of cash acquired, in exchange for these assets and operations. The acquisition agreement also contemplates a post-closing adjustment to the purchase price for certain working capital items. We incurred and charged to general and administrative expense $5.3 million of costs during the year ended March 31, 2014 related to the acquisition of Gavilon Energy.
	We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in this business combination. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2015. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):										The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana and a 50% interest in Glass Mountain, which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma. This pipeline became operational in February 2014. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids.
	Cash and cash equivalents	$	1,469								We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in the acquisition of Gavilon Energy. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending September 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	Accounts receivable - trade	197,349
	Accounts receivable - affiliates	528									Accounts receivable - trade	$	349,529
	Inventories	426,913									Accounts receivable - affiliates	2,564
	Prepaid expenses and other current assets	15,373									Inventories	107,430
	Property, plant and equipment:										Prepaid expenses and other current assets	68,322
	Refined products terminal assets (20 years)	418,405									Property, plant and equipment:
	Buildings and leasehold improvements (20 years)	10,339									Crude oil tanks and related equipment (3—40 years)	77,429
	Crude oil tanks and related equipment (20 years)	28,666									Vehicles (3 years)	791
	Vehicles	1,565									Information technology equipment (3—7 years)	4,046
	Land	56,095									Buildings and leasehold improvements (3—40 years)	7,716
	Information technology equipment	7,851									Land	6,427
	Other	12,592									Linefill and tank bottoms	15,230
	Construction in progress	4,487									Other (7 years)	170
	Goodwill (1)	29,118									Construction in process	7,190
	Intangible assets:										Goodwill	359,169
	Customer relationships (7 years)	50,000									Intangible assets:
	Pipeline capacity rights (30 years)	87,000									Customer relationships (10—20 years)	101,600
	Trade names (indefinite life)	5,000									Lease agreements (1—5 years)	8,700
	Equity method investments	250,000									Investments in unconsolidated entities	178,000
	Other noncurrent assets	3,911									Other noncurrent assets	9,918
	Accounts payable - trade	(140,597		)							Accounts payable - trade	(342,792		)
	Accounts payable - affiliates	(69		)							Accounts payable - affiliates	(2,585		)
	Accrued expenses and other payables	(73,565		)							Accrued expenses and other payables	(70,999		)
	Advance payments received from customers	(1,919		)							Advance payments received from customers	(10,667		)
	Long-term debt	(234,000		)							Other noncurrent liabilities	(44,740		)
	Other noncurrent liabilities	(34,856		)							Fair value of net assets acquired	$	832,448
	Noncontrolling interests	(567,120		)
	Fair value of net assets acquired	$	554,535								Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership, the opportunity to use the acquired business as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
											Our preliminary estimate of the fair value of investments in unconsolidated subsidiaries exceeds our share of the historical net book value of these subsidiaries’ net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.
	(1)     Included in the refined products and renewables segment.
											The acquisition method of accounting requires that executory contracts that are at unfavorable terms relative to current market conditions at the acquisition date be recorded as assets or liabilities in the acquisition accounting. Since certain crude oil storage lease commitments were at unfavorable terms relative to current market conditions, we recorded a liability of $12.9 million related to these lease commitments in the acquisition accounting, and we amortized $2.9 million of this balance through cost of sales during the period from the acquisition date through March 31, 2014. We will amortize the remainder of this liability over the term of the leases. The future amortization of this liability is shown below (in thousands):
	Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership, the opportunity to use the acquired business as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
											Year Ending March 31,
	The intangible asset for pipeline capacity rights relates to capacity allocations on a third-party refined products pipeline. Demand for use of this pipeline exceeds the pipeline’s capacity, and the limited capacity is allocated based on a shipper’s historical shipment volumes.										2015	$	6,500
											2016	3,260
	The fair value of the noncontrolling interests was calculated by multiplying the closing price of TLP’s common units on the acquisition date by the number of TLP common units held by parties other than us.										2017	300
	We recorded in the acquisition accounting a liability of $2.5 million related to certain crude oil contracts with terms that were unfavorable at current market conditions. We amortized this balance to cost of sales during the three months ended September 30, 2014.
											As described in Note 14, on March 31, 2014, we assigned all of the storage and transportation contracts of the natural gas marketing business to a third party.  Since these contracts were at unfavorable terms relative to current market conditions, we paid $44.8 million to assign these contracts. We recorded a liability of $50.8 million related to these storage and transportation contracts in the acquisition accounting, and we amortized $6.0 million of this balance through cost of sales during the period from the acquisition date through the date we assigned the contracts.
	Employees of TransMontaigne participate in a plan whereby they are entitled to certain termination benefits in the event of a change in control of TransMontaigne and a subsequent change in job status. We recorded expense of $2.7 million during the three months ended September 30, 2014 related to these termination benefits, and we may record additional expense in future quarters as we continue our integration efforts.
											We recorded $3.2 million of employee severance expense during the year ended March 31, 2014 as a result of personnel changes subsequent to the acquisition of Gavilon Energy. In addition, certain personnel who were employees of Gavilon Energy are entitled to a bonus, half of which was payable upon successful completion of the business combination and the remainder of which is payable in December 2014. We are recording this as compensation expense over the vesting period. We recorded expense of $5.0 million during the year ended March 31, 2014 related to these bonuses, and we expect to record an additional expense of $6.6 million during the year ending March 31, 2015.
	The operations of TransMontaigne have been included in our condensed consolidated statements of operations since TransMontaigne was acquired on July 1, 2014. Our condensed consolidated statements of operations for the three months and six months ended September 30, 2014 include revenues of $1.1 billion and an operating loss of $0.3 million that were generated by the operations of TransMontaigne. We have not provided supplemental pro forma financial information as though the business combination had occurred on April 1, 2013. The previous owner of TransMontaigne conducted trading operations, whereas we strive to generate reliable and predictable cash flows. Because of the difference in strategies between the pre-acquisition and post-acquisition periods, the pre-acquisition operations of TransMontaigne have limited importance as an indicator of post-acquisition results.
											The operations of Gavilon Energy have been included in our consolidated statement of operations since Gavilon Energy was acquired on December 2, 2013. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $2.9 billion and operating income of $11.0 million that were generated by the operations of Gavilon Energy.
	On July 10, 2014, we submitted a nonbinding proposal to the conflicts committee of the board of directors of TLP’s general partner. Under this proposal, each outstanding unit of TLP would be exchanged for one of our common units. On August 15, 2014, we and TLP’s general partner terminated discussions regarding our previously submitted nonbinding proposal to acquire the outstanding common units of TLP.
											Oilfield Water Lines, LP
	Water Solutions Facilities
											On August 2, 2013, we completed a business combination with entities affiliated with OWL, whereby we acquired water disposal and transportation assets in Texas. We issued 2,463,287 common units, valued at $68.6 million, and paid $167.7 million of cash, net of cash acquired, in exchange for OWL. The acquisition agreements included a provision whereby the purchase price could have been increased if certain performance targets were achieved in the six months following the acquisition. These performance targets were not achieved, and therefore no increase to the purchase price was warranted. The acquisition agreements also contemplate a post-closing payment for certain working capital items. We incurred and charged to general and administrative expense $0.8 million of costs related to the OWL acquisition during the year ended March 31, 2014.
	As described below, we are party to a development agreement that provides us a right to purchase water disposal facilities developed by the other party to the agreement. During the six months ended September 30, 2014, we purchased four water disposal facilities under this development agreement. We also purchased a 75% interest in one additional water disposal facility in July 2014 from a different seller. On a combined basis, we paid $82.9 million of cash for these five water disposal facilities.
											We have completed the process of identifying and determining the fair value of the long-lived assets acquired in the acquisition of OWL. We have not yet finalized any post-closing payment for certain working capital items, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these business combinations. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2015. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
											Accounts receivable - trade	$	7,268
	Accounts receivable - trade	$	939								Inventories	154
	Inventories	253									Prepaid expenses and other current assets	402
	Prepaid expenses and other current assets	62									Property, plant and equipment:
	Property, plant and equipment:										Land	710
	Water treatment facilities and equipment (5–40 years)	23,066									Water treatment facilities and equipment (3—30 years)	23,173
	Buildings and leasehold improvements (3–7 years)	2,599									Vehicles (5—10 years)	8,157
	Land	1,010									Buildings and leasehold improvements (7—30 years)	2,198
	Other (7 years)	33									Other (3—5 years)	53
Goodwill	57,777									Intangible assets:
Other noncurrent assets	50									Customer relationships (10 years)	110,000
Accounts payable - trade	(58		)							Non-compete agreements (2.5 years)	2,000
Accrued expenses and other payables	(1,092		)							Goodwill	89,699
Other noncurrent liabilities	(149		)							Accounts payable - trade	(6,469		)
Noncontrolling interest	(1,620		)							Accrued expenses and other payables	(992		)
Fair value of net assets acquired	$	82,870								Other noncurrent liabilities	(64		)
										Fair value of net assets acquired	$	236,289
Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership and the opportunity to use the acquired business as a platform for growth. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Consideration paid consists of the following (in thousands):
The operations of these water disposal facilities have been included in our condensed consolidated statement of operations since their acquisition date. Our condensed consolidated statement of operations for the quarter ended September 30, 2014 includes revenues of $7.1 million and operating income of $1.5 million that were generated by the operations of these water disposal facilities.
										Cash paid, net of cash acquired	$	167,732
Retail Propane Acquisitions										Value of common units issued	68,557
										Total consideration paid	$	236,289
During the six months ended September 30, 2014, we completed three acquisitions of retail propane businesses. On a combined basis, we paid $6.4 million of cash to acquire these assets and operations. The agreements for these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result, the estimates of fair value reflected at September 30, 2014 are subject to change.
										The customer relationships were valued using a variation of the income approach known as the excess earnings method. This methodology consists of deriving relevant cash flows to the underlying asset, and then deducting appropriate returns for other assets contributing to the generation of the relevant cash flows. This valuation methodology requires estimates of customer retention, which were based on our understanding of the level of competition in the region in which the assets operate. Our estimates of customer retention are also relevant to the determination of the estimated useful lives of the assets.
Water Supply Company
										Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
On June 9, 2014, we paid cash of $15.0 million in exchange for an interest in a water supply company operating in the DJ Basin. We account for this investment using the equity method of accounting.
										The operations of OWL have been included in our consolidated statement of operations since OWL was acquired on August 2, 2013. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $26.2 million and operating income of $0.9 million that was generated by the operations of OWL.
Year Ended March 31, 2014
										Other Water Solutions Acquisitions
As described in Note 2, pursuant to GAAP, an entity is allowed a reasonable period of time to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. The business combinations for which this measurement period was still open as of March 31, 2014 are summarized below.
										During the year ended March 31, 2014, we completed four separate acquisitions of businesses to expand our water solutions operations in Texas. On a combined basis, we issued 222,381 common units, valued at $6.8 million, and paid $178.9 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $20.6 million and operating income of $7.1 million that was generated by the operations of these acquisitions. We incurred and charged to general and administrative expense $0.4 million of costs related to these acquisitions during the year ended March 31, 2014.
Gavilon Energy
										We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these four business combinations. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending September 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
On December 2, 2013, we completed a business combination in which we acquired Gavilon Energy. We paid $832.4 million of cash, net of cash acquired, in exchange for these assets and operations. The acquisition agreement also contemplates a post-closing adjustment to the purchase price for certain working capital items.
										Accounts receivable - trade	$	2,391
The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana, a 50% interest in Glass Mountain, which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma, and an 11% interest in an ethanol production facility in the Midwest. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids and owned and leased crude oil storage in Cushing, Oklahoma.										Inventories	390
										Prepaid expenses and other current assets	61
During the three months ended September 30, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for this acquisition:										Property, plant and equipment:
										Land	419
				Estimated at						Vehicles (5—10 years)	90
				at						Water treatment facilities and equipment (3—30 years)	24,933
				March 31,						Buildings and leasehold improvements (7—30 years)	3,036
	Final			2014			Change			Other (3—5 years)	13
	(in thousands)									Intangible assets:
Accounts receivable - trade	$	326,484		$	349,529		$	(23,045	)	Customer relationships (8—10 years)	72,000
Accounts receivable - affiliates	2,564			2,564			—			Trade names (indefinite life)	3,325
Inventories	107,430			107,430			—			Non-compete agreements (3 years)	260
Prepaid expenses and other current assets	68,322			68,322			—			Water facility development agreement (5 years)	14,000
Property, plant and equipment:										Water facility option agreement	2,500
Vehicles (3 years)	327			791			(464		)	Goodwill	63,031
Crude oil tanks and related equipment (3–40 years)	83,797			77,429			6,368			Accounts payable - trade	(382		)
Information technology equipment (3–7 years)	4,049			4,046			3			Accrued expenses and other payables	(300		)
Buildings and leasehold improvements (3–40 years)	7,817			7,716			101			Other noncurrent liabilities	(114		)
Land	6,427			6,427			—			Fair value of net assets acquired	$	185,653
Tank bottoms	16,930			15,230			1,700
Other (7 years)	162			170			(8		)	Consideration paid consists of the following (in thousands):
Construction in progress	7,180			7,190			(10		)
Goodwill (1)	342,769			359,169			(16,400		)	Cash paid, net of cash acquired	$	178,867
Intangible assets:										Value of common units issued	6,786
Customer relationships (10–20 years)	107,950			101,600			6,350			Total consideration paid	$	185,653
Lease agreements (1–5 years)	8,700			8,700			—
Pipeline capacity rights (30 years)	7,800			—			7,800			Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Investments in unconsolidated entities	183,000			178,000			5,000
Other noncurrent assets	2,287			9,918			(7,631		)	As part of one of these business combinations, we entered into an option agreement with the seller of the business whereby we had the option to purchase a salt water disposal facility that was under construction. We recorded an intangible asset of $2.5 million at the acquisition date related to this option agreement. On March 1, 2014, we purchased the saltwater disposal facility for additional cash consideration of $3.7 million. The assets associated with this facility are included in the data in the table above.
Accounts payable - trade	(342,792		)	(342,792		)	—
Accounts payable - affiliates	(2,585		)	(2,585		)	—			As part of one of these business combinations, we entered into a development agreement that provides us a first right of refusal to purchase disposal facilities that may be developed by the seller within a defined area in the Eagle Ford Basin through June 2018. On March 1, 2014, we purchased our first disposal facility pursuant to the development agreement for $21.0 million. The assets associated with this facility are included in the data in the table above. In addition, we have exercised our option to operate, for evaluation purposes, three additional disposal facilities developed by the seller. Pending the results of our evaluation, we have the right to purchase any or all of these facilities within the 90-day evaluation period.
Accrued expenses and other payables	(49,447		)	(70,999		)	21,552
Advance payments received from customers	(10,667		)	(10,667		)	—			Crude Oil Logistics Acquisitions
Other noncurrent liabilities	(46,056		)	(44,740		)	(1,316		)
Fair value of net assets acquired	$	832,448		$	832,448		$	—		During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our crude oil logistics business in Texas and Oklahoma. On a combined basis, we issued 175,211 common units, valued at $5.3 million, and paid $67.8 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. The agreement for the acquisition of one of these businesses contemplates a post-closing payment for certain working capital items. We incurred and charged to general and administrative expense during the year ended March 31, 2014 $0.1 million of costs related to these acquisitions.
										We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these two business combinations. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
(1)     Primarily included in the crude oil logistics segment.
										Accounts receivable - trade	$	1,235
We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.										Inventories	1,021
										Prepaid expenses and other current assets	54
The acquisition method of accounting requires that executory contracts that are at unfavorable terms relative to current market conditions at the acquisition date be recorded as assets or liabilities in the acquisition accounting. Since certain crude oil storage lease commitments were at unfavorable terms relative to current market conditions, we recorded a liability of $15.9 million related to these lease commitments in the acquisition accounting, and we amortized $5.0 million of this balance through cost of sales during the six months ended September 30, 2014. We will amortize the remainder of this liability over the term of the leases. The future amortization of this liability is shown below (in thousands):										Property, plant and equipment:
										Vehicles (5—10 years)	2,977
Year Ending March 31,										Buildings and leasehold improvements (5—30 years)	280
2015 (six months)	$	3,670								Crude oil tanks and related equipment (2—30 years)	3,462
2016	4,040									Barges and towboats (20 years)	20,065
2017	360									Other (3—5 years)	53
										Intangible assets:
										Customer relationships (3 years)	6,300
Certain personnel who were employees of Gavilon Energy are entitled to a bonus, half of which was payable upon successful completion of the business combination and the remainder of which is payable in December 2014. We are recording this as compensation expense over the vesting period. We recorded expense of $5.2 million during the six months ended September 30, 2014 related to these bonuses, and we expect to record an additional expense of $1.6 million during the quarter ending December 31, 2014.										Non-compete agreements (3 years)	35
										Trade names (indefinite life)	530
Oilfield Water Lines, LP										Goodwill	37,867
										Accounts payable - trade	(665		)
On August 2, 2013, we completed a business combination with entities affiliated with Oilfield Water Lines LP (collectively, “OWL”), whereby we acquired water disposal and transportation assets in Texas. We issued 2,463,287 common units, valued at $68.6 million, and paid $167.7 million of cash, net of cash acquired, in exchange for OWL. During the three months ended June 30, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed in the acquisition of OWL:										Accrued expenses and other payables	(124		)
										Fair value of net assets acquired	$	73,090
				Estimated
				at						Consideration paid consists of the following (in thousands):
				March 31,
	Final			2014			Change			Cash paid, net of cash acquired	$	67,842
	(in thousands)									Value of common units issued	5,248
Accounts receivable - trade	$	6,837		$	7,268		$	(431	)	Total consideration paid	$	73,090
Inventories	154			154			—
Prepaid expenses and other current assets	402			402			—			Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Property, plant and equipment:
Vehicles (5–10 years)	8,143			8,157			(14		)	Retail Propane and Liquids Acquisitions
Water treatment facilities and equipment (3–30 years)	23,173			23,173			—
Buildings and leasehold improvements (7–30 years)	2,198			2,198			—			During the year ended March 31, 2014, we completed four acquisitions of retail propane businesses and the acquisition of four natural gas liquids terminals. On a combined basis, we paid $21.9 million of cash to acquire these assets and operations. The agreements for certain of these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result the estimates of fair value reflected at March 31, 2014 are subject to change.
Land	710			710			—
Other (3–5 years)	53			53			—			Year Ended March 31, 2013
Intangible assets:
Customer relationships (8–10 years)	110,000			110,000			—			High Sierra Combination
Non-compete agreements (3 years)	2,000			2,000			—
Goodwill	90,144			89,699			445			On June 19, 2012, we completed a business combination with High Sierra, whereby we acquired all of the ownership interests in High Sierra. We paid $91.8 million of cash, net of $5.0 million of cash acquired, and issued 18,018,468 common units to acquire High Sierra Energy, LP. These common units were valued at $406.8 million using the closing price of our common units on the New York Stock Exchange (the “NYSE”) on the merger date. We also paid $97.4 million of High Sierra Energy, LP’s long-term debt and other obligations. Our general partner acquired High Sierra Energy GP, LLC by paying $50.0 million of cash and issuing equity. Our general partner then contributed its ownership interests in High Sierra Energy GP, LLC to us, in return for which we paid our general partner $50.0 million of cash and issued 2,685,042 common units to our general partner. We recorded the value of the 2,685,042 common units issued to our general partner at $8.0 million, which represents an estimate, in accordance with GAAP, of the fair value of the equity issued by our general partner to the former owners of High Sierra’s general partner. In accordance with the GAAP fair value model, this fair value was estimated based on assumptions of future distributions and a discount rate that a hypothetical buyer might use. Under this model, the potential for distribution growth resulting from the prospect of future acquisitions and capital expansion projects would not be considered in the fair value calculation. The difference between the estimated fair value of the general partner interests issued by our general partner of $8.0 million, calculated as described above, and the fair value of the common units issued to our general partner of $60.6 million, as calculated using the closing price of the common units on the NYSE, is reported as a reduction to equity. We incurred and charged to general and administrative expense during the years ended March 31, 2013 $3.7 million of costs related to the High Sierra transaction. We also incurred or accrued costs of $0.6 million related to the equity issuance that we charged to equity.
Accounts payable - trade	(6,469		)	(6,469		)	—
Accrued expenses and other payables	(992		)	(992		)	—			The fair values of the assets acquired and liabilities assumed in our acquisition of High Sierra are summarized below (in thousands):
Other noncurrent liabilities	(64		)	(64		)	—
Fair value of net assets acquired	$	236,289		$	236,289		$	—		Accounts receivable - trade	$	395,311
										Accounts receivable - affiliates	7,724
We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.										Inventories	43,575
										Derivative assets	10,646
Other Water Solutions Acquisitions										Forward purchase and sale contracts	34,717
										Prepaid expenses and other current assets	11,131
During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our water solutions operations in Texas. On a combined basis, we issued 222,381 common units, valued at $6.8 million, and paid $151.6 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:										Property, plant and equipment:
										Land	5,723
				Estimated						Vehicles (5—10 years)	22,507
				at						Water treatment facilities and equipment (3—30 years)	64,057
				March 31,						Crude oil tanks and related equipment (2—15 years)	17,851
	Final			2014			Change			Buildings and leasehold improvements (5—30 years)	19,145
	(in thousands)									Information technology equipment (3 years)	5,541
Accounts receivable - trade	$	2,146		$	2,146		$	—		Other (2—30 years)	11,010
Inventories	192			192			—			Construction in progress	9,621
Prepaid expenses and other current assets	62			61			1			Intangible assets:
Property, plant and equipment:										Customer relationships (5—17 years)	245,000
Vehicles (5–10 years)	76			90			(14		)	Lease contracts (1—10 years)	12,400
Water treatment facilities and equipment (3–30 years)	11,717			14,394			(2,677		)	Trade names (indefinite)	13,000
Buildings and leasehold improvements (7–30 years)	3,278			1,906			1,372			Goodwill	220,884
Land	207			206			1			Accounts payable - trade	(417,369			)
Other (3–5 years)	12			12			—			Accounts payable - affiliates	(9,014			)
Intangible assets:										Advance payments received from customers	(1,237			)
Customer relationships (8–10 years)	72,000			72,000			—			Accrued expenses and other payables	(35,611			)
Trade names (indefinite life)	3,325			3,325			—			Derivative liabilities	(5,726			)
Non-compete agreements (3 years)	260			260			—			Forward purchase and sale contracts	(18,680			)
Water facility development agreement (5 years)	14,000			14,000			—			Long-term debt	(2,537			)
Water facility option agreement	2,500			2,500			—			Other noncurrent liabilities	(3,224			)
Goodwill	49,067			47,750			1,317			Noncontrolling interest in consolidated subsidiary	(2,400			)
Accounts payable - trade	(119		)	(119		)	—			Consideration paid, net of cash acquired	$		654,045
Accrued expenses and other payables	(293		)	(293		)	—
Other noncurrent liabilities	(64		)	(64		)	—
Fair value of net assets acquired	$	158,366		$	158,366		$	—		Consideration paid consists of the following (in thousands):
As part of one of these business combinations, we entered into an option agreement with the seller of the business whereby we had the option to purchase a saltwater disposal facility that was under construction. We recorded an intangible asset of $2.5 million at the acquisition date related to this option agreement. On March 1, 2014, we purchased the saltwater disposal facility for additional cash consideration of $3.7 million.										Cash paid, net of cash acquired	$	239,251
										Value of common units issued, net of issurance costs	414,794
In addition, as part of one of these business combinations, we entered into a development agreement that provides us a right to purchase water disposal facilities that may be developed by the seller through June 2018. On March 1, 2014, we purchased our first water disposal facility pursuant to the development agreement for $21.0 million.										Total consideration paid	$	654,045
We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these business combinations. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending December 31, 2014. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows:										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.
	Estimated At									Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
	September 30,			March 31,
	2014			2014			Change			Pecos Combination
	(in thousands)
Accounts receivable - trade	$	124		$	245		$	(121	)	On November 1, 2012, we completed a business combination whereby we acquired Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”). The business of Pecos consists primarily of crude oil marketing and logistics operations in Texas and New Mexico. We paid $132.4 million of cash (net of cash acquired) and assumed certain obligations with a value of $10.2 million under certain equipment financing facilities. Also on November 1, 2012, we entered into a call agreement with the former owners of Pecos pursuant to which the former owners of Pecos agreed to purchase a minimum of $45.0 million or a maximum of $60.0 million of common units from us. On November 12, 2012, the former owners purchased 1,834,414 common units from us for $45.0 million pursuant to this call agreement. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.6 million of costs related to the Pecos combination.
Inventories	119			197			(78		)
Property, plant and equipment:										The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of Pecos:
Water treatment facilities and equipment (3–30 years)	10,539			10,540			(1		)
Buildings and leasehold improvements (7–30 years)	1,130			1,130			—							Estimated at
Land	213			213			—							March 31,
Other (3–5 years)	1			1			—				Final			2013			Change
Goodwill	15,443			15,281			162				(in thousands)
Accounts payable - trade	(232		)	(263		)	31			Accounts receivable - trade	$	73,609		$	73,704		$	(95	)
Accrued expenses and other payables	—			(7		)	7			Inventories	1,903			1,903			—
Other noncurrent liabilities	(50		)	(50		)	—			Prepaid expenses and other current assets	1,426			1,426			—
Fair value of net assets acquired	$	27,287		$	27,287		$	—		Property, plant and equipment:
										Vehicles (5—10 years)	22,097			19,193			2,904
Crude Oil Logistics Acquisitions										Buildings and leasehold improvements (5—30 years)	1,339			1,248			91
										Crude oil tanks and related equipment (2—15 years)	1,099			913			186
During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our crude oil logistics operations in Texas and Oklahoma. On a combined basis, we issued 175,211 common units, valued at $5.3 million, and paid $67.8 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:										Land	223			224			(1		)
										Other (3—5 years)	36			177			(141		)
				Estimated						Intangible assets:
				at						Customer relationships	—			8,000			(8,000		)
				March 31,						Trade names (indefinite life)	900			1,000			(100		)
	Final			2014			Change			Goodwill	91,747			86,661			5,086
	(in thousands)									Accounts payable - trade	(50,795		)	(50,808		)	13
Accounts receivable - trade	$	1,221		$	1,235		$	(14	)	Accrued expenses and other payables	(963		)	(1,020		)	57
Inventories	1,021			1,021			—			Long-term debt	(10,234		)	(10,234		)	—
Prepaid expenses and other current assets	58			54			4			Fair value of net assets acquired	$	132,387		$	132,387		$	—
Property, plant and equipment:
Vehicles (5–10 years)	2,980			2,977			3			Consideration paid consists of the following (in thousands):
Buildings and leasehold improvements (5–30 years)	58			280			(222		)
Crude oil tanks and related equipment (2–30 years)	3,822			3,462			360			Cash paid, net of cash acquired	$	87,444
Barges and towboats (20 years)	20,065			20,065			—			Value of common units issued	44,943
Other (3–5 years)	57			53			4			Total consideration paid	$	132,387
Intangible assets:
Customer relationships (3 years)	13,300			6,300			7,000			Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Non-compete agreements (3 years)	35			35			—
Trade names (indefinite life)	530			530			—			Third Coast Combination
Goodwill	30,730			37,867			(7,137		)
Accounts payable - trade	(521		)	(665		)	144			On December 31, 2012, we completed a business combination transaction whereby we acquired all of the membership interests in Third Coast Towing, LLC (“Third Coast”) for $43.0 million in cash. The business of Third Coast consists primarily of transporting crude oil via barge. Also on December 31, 2012, we entered into a call agreement with the former owners of Third Coast pursuant to which the former owners of Third Coast agreed to purchase a minimum of $8.0 million or a maximum of $10.0 million of common units from us. On January 11, 2013, the former owners of Third Coast purchased 344,680 common units from us for $8.0 million pursuant to this agreement.
Accrued expenses and other payables	(266		)	(124		)	(142		)
Fair value of net assets acquired	$	73,090		$	73,090		$	—		During the year ended March 31, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of Third Coast:
Retail Propane and Liquids Acquisitions														Estimated at
														March 31,
During the year ended March 31, 2014, we completed four acquisitions of retail propane businesses and the acquisition of four natural gas liquids terminals. On a combined basis, we paid $21.9 million of cash to acquire these assets and operations. The agreements for certain of these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result, the estimates of fair value reflected at September 30, 2014 are subject to change.											Final			2013			Change
											(in thousands)
										Accounts receivable - trade	$	2,195		$	2,248		$	(53	)
										Inventories	140			140			—
										Property, plant and equipment:
										Barges and towboats (20 years)	17,711			12,883			4,828
										Other	—			30			(30		)
										Intangible assets:
										Customer relationships (3 years)	3,000			4,000			(1,000		)
										Trade names (indefinite life)	850			500			350
										Goodwill	18,847			22,551			(3,704		)
										Other noncurrent assets	2,733			2,733			—
										Accounts payable - trade	(2,429		)	(2,048		)	(381		)
										Accrued expenses and other payables	(164		)	(154		)	(10		)
										Fair value of net assets acquired	$	42,883		$	42,883		$	—
										Consideration paid consists of the following (in thousands):
										Cash paid, net of cash acquired	$	35,000
										Value of common units issued	7,883
										Total consideration paid	$	42,883
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Other Crude Oil Logistics and Water Solutions Business Combinations
										During the year ended March 31, 2013, we completed four separate acquisitions to expand the assets and operations of our crude oil logistics and water solutions businesses. On a combined basis, we paid $52.6 million in cash and assumed $1.3 million of long-term debt in the form of non-compete agreements. We also issued 516,978 common units, valued at $12.4 million, as partial consideration for one of these acquisitions. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.3 million of costs related to these acquisitions.
										During the year ended March 31, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of these businesses:
														Estimated at
														March 31,
											Final			2013			Change
											(in thousands)
										Accounts receivable - trade	$	2,676		$	2,660		$	16
										Inventories	191			191			—
										Prepaid expenses and other current assets	737			738			(1		)
										Property, plant and equipment:
										Land	218			191			27
										Vehicles (5—10 years)	853			771			82
										Water treatment facilities and equipment (3—30 years)	13,665			13,322			343
										Buildings and leasehold improvements (5—30 years)	895			2,233			(1,338		)
										Crude oil tanks and related equipment (2—15 years)	4,510			1,781			2,729
										Other (3—5 years)	27			2			25
										Construction in progress	490			693			(203		)
										Intangible assets:
										Customer relationships (5—10 years)	13,125			6,800			6,325
										Non-compete agreements (3 years)	164			510			(346		)
										Trade names (indefinite life)	2,100			500			1,600
										Goodwill	34,451			43,822			(9,371		)
										Accounts payable - trade	(3,374		)	(3,374		)	—
										Accrued expenses and other payables	(1,914		)	(2,026		)	112
										Notes payable	(1,340		)	(1,340		)	—
										Other noncurrent liabilities	(156		)	(156		)	—
										Noncontrolling interest	(2,333		)	(2,333		)	—
										Fair value of net assets acquired	$	64,985		$	64,985		$	—
										Consideration paid consists of the following (in thousands):
										Cash paid, net of cash acquired	$	52,552
										Value of common units issued	12,433
										Total consideration paid	$	64,985
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Retail Propane Combinations During the Year Ended March 31, 2013
										During the year ended March 31, 2013, we entered into six separate business combination agreements to acquire retail propane and distillate operations, primarily in the northeastern and southeastern United States. On a combined basis, we paid cash of $71.4 million and issued 850,676 common units, valued at $18.9 million, in exchange for these assets. We also assumed $6.6 million of long-term debt in the form of non-compete agreements. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.3 million related to these acquisitions. The fair values of the assets acquired and liabilities assumed in these six combinations are as follows (in thousands):
										Accounts receivable - trade	$	8,715
										Inventory	5,155
										Other current assets	1,228
										Property, plant and equipment:
										Land	1,945
										Retail propane equipment (5—20 years)	28,763
										Vehicles (5 years)	11,344
										Buildings and leasehold improvements (30 years)	7,052
										Other	1,201
										Intangible assets:
										Customer relationships (10—15 years)	16,890
										Trade names (indefinite)	2,924
										Non-compete agreements (5 years)	1,387
										Goodwill	21,983
										Other non-current assets	784
										Long-term debt, including current portion	(6,594		)
										Other assumed liabilities	(12,511		)
										Fair value of net assets acquired	$	90,266
										Consideration paid consists of the following (in thousands):
										Cash consideration paid	$	71,392
										Value of common units issued	18,874
										Total consideration	$	90,266
										Goodwill represents the excess of the estimated consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Pro Forma Results of Operations (Unaudited)
										As described above, we completed a number of acquisitions during the years ended March 31, 2014 and 2013. The operations of each acquired business have been included in our consolidated results of operations since the date of acquisition of the business. The unaudited pro forma consolidated data presented below has been prepared as if the following acquisitions had been completed on April 1, 2012:
										·                  High Sierra;
										·                  Pecos;
										·                  Third Coast;
										·                  OWL; and
										·                  Gavilon Energy.
										The unaudited pro forma consolidated data presented below has also been prepared as if the following transactions, which are described in Notes 8 and 11 to these consolidated financial statements, had been completed on April 1, 2012:
										·                  Our sale of common units in December 2013 in a private placement;
										·                  The amendment of our Credit Agreement in November 2013;
										·                  Our issuance of senior unsecured notes in October 2013;
										·                  Our sale of common units in September 2013 in a public offering;
										·                  The sale of common units in a public offering in July 2013;
										·                  Our entry into the Credit Agreement in June 2012; and
										·                  Our issuance of senior notes in June 2012.
											Year Ended March 31,
											2014			2013
											(in thousands, except per unit amounts)
										Revenues	$	9,800,398		$	5,697,988
										Net income (loss)	798			(72,171		)
										Net loss attributable to limited partners	(14,446		)	(75,251		)
										Basic and diluted loss per common unit	(0.18		)	(0.95		)
										Basic and diluted loss per subordinated unit	(0.18		)	(0.95		)
										The pro forma consolidated data in the table above was prepared by adding historical results of operations of acquired businesses to our historical results of operations and making certain pro forma adjustments. The pro forma information is not necessarily indicative of the results of operations that would have occurred if the transactions had occurred on April 1, 2012, nor is it necessarily indicative of future results of operations.
										Gavilon Energy historically conducted trading operations, whereas we operate as a logistics business. Gavilon Energy’s historical results of operations were subject to more volatility as a result of its trading operations than we would expect future results of operations to have under our business model. In the pro forma data in the table above, no pro forma effect was given to the change in business model from a trading business to a logistics business. Gavilon Energy historically recorded revenues net of product costs. In the pro forma table above, no pro forma effect was given to the fact that this accounting policy is different than our accounting policy.
										The pro forma net loss for the year ended March 31, 2013 in the table above includes $4.8 million of expense related to the retirement of a liability associated with a business combination that OWL completed prior to our acquisition of OWL. This non-recurring expense is not excluded from the pro forma net loss, as it does not directly result from our acquisition of OWL.
										The pro forma net loss for the year ended March 31, 2014 shown in the table above reflects depreciation and amortization expense estimates which are preliminary, as our identification of the assets and liabilities acquired, and the fair value determinations thereof, for the business combination with Gavilon Energy have not been completed.
										The pro forma losses per unit have been computed based on earnings or losses allocated to the limited partners after deducting the total earnings allocated to the general partner. To calculate earnings attributable to the general partner, we have used historical distribution amounts. For purposes of this calculation, we have assumed that the common units outstanding at March 31, 2014 were outstanding during the full years presented above.
										Year Ended March 31, 2012
										Osterman
										On October 3, 2011, we completed a business combination transaction with Osterman, whereby we acquired retail propane operations in the northeastern United States. We issued 4,000,000 common units and paid $94.9 million of cash, net of cash acquired, in exchange for the assets and operations of Osterman. The agreement also contemplated a post-closing payment of $4.8 million for certain specified working capital items, which was paid in November 2012. We valued the 4 million limited partner common units at $81.9 million based on the closing price of our common units on the closing date ($20.47 per unit). We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.8 million of costs incurred in connection with the Osterman transaction. We also incurred costs related to the equity issuance of $0.1 million that we charged to equity. The following table presents the final allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	9,350
										Inventories	3,869
										Prepaid expenses and other current assets	215
										Property, plant and equipment:
										Land	2,349
										Retail propane equipment (15—20 years)	47,160
										Vehicles (5—20 years)	7,699
										Buildings and leasehold improvements (30 years)	3,829
										Other (3—5 years)	732
										Intangible assets:
										Customer relationships (20 years)	54,500
										Trade names (indefinite life)	8,500
										Non-compete agreements (7 years)	700
										Goodwill	52,267
										Assumed liabilities	(9,654		)
										Consideration paid, net of cash acquired	$	181,516
										Consideration paid consists of the following (in thousands):
										Cash paid at closing, net of cash acquired	$	94,873
										Fair value of common units issued at closing	81,880
										Working capital payment (paid in November 2012)	4,763
										Consideration paid, net of cash acquired	$	181,516
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										SemStream
										On November 1, 2011, we completed a business combination with SemStream. We entered into this business combination in order to expand our liquids segment. SemStream contributed substantially all of its natural gas liquids business and assets to us in exchange for 8,932,031 of our limited partner common units and a cash payment of $91.0 million. We have valued the 8.9 million limited partner common units at $184.8 million, based on the closing price of our common units on the closing date ($21.07) reduced by the expected present value of distributions for certain units which were not eligible for full distributions until the quarter ending September 30, 2012. In addition, in exchange for a cash contribution, SemStream acquired a 7.5% interest in our general partner. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.7 million of costs related to the SemStream transaction. We also incurred costs of less than $0.1 million related to the equity issuance that we charged to equity.
										The acquired assets included 12 natural gas liquids terminals in Arizona, Arkansas, Indiana, Minnesota, Missouri, Montana, Washington and Wisconsin, 12 million gallons of aboveground propane storage, 3.7 million barrels of underground leased storage for natural gas liquids and a rail fleet of 350 leased and 12 owned cars.
										We have included the results of SemStream’s operations in our consolidated financial statements beginning November 1, 2011. The operations of SemStream are reflected in our liquids segment.
										The following table presents the fair values of the assets acquired and liabilities assumed in the SemStream combination (in thousands):
										Inventories	$	104,226
										Derivative assets	3,578
										Assets held for sale	3,000
										Prepaid expenses and other current assets	9,833
										Property, plant and equipment:
										Land	3,470
										Natural gas liquids terminal assets (20—30 years)	41,434
										Vehicles and railcars (5 years)	470
										Other (5 years)	3,326
										Investment in capital lease	3,112
										Intangible assets:
										Customer relationships (8—15 years)	31,950
										Lease contracts (1—4 years)	1,008
										Goodwill	74,924
										Assumed current liabilities	(4,591		)
										Consideration paid	$	275,740
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired operations and the Partnership, the opportunity to use the acquired businesses as a platform to expand our wholesale marketing operations, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Pacer Combination
										On January 3, 2012, we completed a business combination with Pacer in order to expand our retail propane operations. The combination was funded with cash of $32.2 million and the issuance of 1.5 million common units. We valued the 1.5 million common units based on the closing price of our common units on the closing date. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.7 million of costs related to the Pacer transaction. We also incurred costs of $0.1 million related to the equity issuance that we charged to equity.
										The assets contributed by Pacer consist of retail propane operations in Colorado, Illinois, Mississippi, Oregon, Utah and Washington. The contributed assets include 17 owned or leased customer service centers and satellite distribution locations. We have included the results of Pacer’s operations in our consolidated financial statements beginning January 3, 2012. The operations of Pacer are reported within our retail propane segment.
										Consideration paid consists of the following (in thousands):
										Cash	$	32,213
										Common units	30,375
										Consideration paid	$	62,588
										The following table presents the allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	4,389
										Inventories	965
										Prepaid expenses and other current assets	43
										Property, plant and equipment:
										Land	1,967
										Retail propane equipment (15—20 years)	12,793
										Vehicles (5 years)	3,090
										Buildings and leasehold improvements (30 years)	409
										Other (3—5 years)	59
										Intangible assets:
										Customer relationships (15 years)	23,560
										Trade names (indefinite life)	2,410
										Non-compete agreements	1,520
										Goodwill	15,782
										Assumed liabilities	(4,399		)
										Consideration paid	$	62,588
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										North American Combination
										On February 3, 2012, we completed a business combination with North American in order to expand our retail propane operations. The combination was funded with cash of $69.8 million. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $1.6 million of costs related to the North American acquisition.
										The assets acquired from North American include retail propane and distillate operations in Connecticut, Delaware, Maine, Maryland, Massachusetts, New Hampshire, New Jersey, Pennsylvania, and Rhode Island.
										The following table presents the allocation of the acquisition costs to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	10,338
										Inventories	3,437
										Prepaid expenses and other current assets	282
										Property, plant and equipment:
										Land	2,251
										Retail propane equipment (15—20 years)	24,790
										Natural gas liquids terminal assets (15—20 years)	1,044
										Vehicles (5—15 years)	5,819
										Buildings and leasehold improvements (30 years)	2,386
										Other (3—5 years)	634
										Intangible assets:
										Customer relationships (10 years)	12,600
										Trade names (10 years)	2,700
										Non-compete agreements (3 years)	700
										Goodwill	13,978
										Assumed liabilities	(11,129		)
										Consideration paid	$	69,830
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Other Acquisitions
										During the year ended March 31, 2012, we closed three additional acquisitions for cash payments of $6.4 million on a combined basis. We also assumed $0.6 million in long-term debt in the form of non-compete agreements. These operations have been included in our results of operations since the acquisition dates, and have not been material to our consolidated financial statements.

Property_Plant_and_Equipment

Property, Plant and Equipment	6 Months Ended						12 Months Ended
	Sep. 30, 2014						Mar. 31, 2014
Property, Plant and Equipment
Property, Plant and Equipment	Note 5 — Property, Plant and Equipment						Note 5 — Property, Plant and Equipment
	Our property, plant and equipment consists of the following:						Our property, plant and equipment consists of the following:
		September 30,		March 31,				March 31,
	Description and Estimated Useful Lives	2014		2014							2013
		(in thousands)					Description and Estimated Useful Lives	2014			(Note 2)
	Natural gas liquids terminal assets (2–30 years)	$	127,258	$	75,141			(in thousands)
	Refined products and renewables terminal assets and equipment (20 years)	419,411		—			Natural gas liquids terminal assets (2—30 years)	$	75,141		$	63,637
	Retail propane equipment (2–30 years)	167,825		160,758			Retail propane equipment (2—30 years)	160,758			152,802
	Vehicles and railcars (3–25 years)	172,799		152,676			Vehicles (3—25 years)	152,676			88,173
	Water treatment facilities and equipment (3–30 years)	209,644		180,985			Water treatment facilities and equipment (3—30 years)	180,985			91,944
	Crude oil tanks and related equipment (2–40 years)	145,287		106,125			Crude oil tanks and related equipment (2—40 years)	106,125			22,577
	Barges and towboats (5–40 years)	56,094		52,217			Barges and towboats (5—40 years)	52,217			25,963
	Information technology equipment (3–7 years)	30,519		20,768			Information technology equipment (3—7 years)	20,768			12,169
	Buildings and leasehold improvements (3–40 years)	77,415		60,004			Buildings and leasehold improvements (3—40 years)	60,004			48,975
	Land	88,350		30,241			Land	30,241			21,815
	Tank bottoms	17,679		13,403			Linefill and tank bottoms	13,403			—
	Other (3–30 years)	16,770		6,341			Other (5—30 years)	6,341			16,104
	Construction in progress	57,319		80,251			Construction in progress	80,251			32,405
		1,586,370		938,910				938,910			576,564
	Less: Accumulated depreciation	-153,057		(109,564		)	Less: Accumulated depreciation	(109,564		)	(50,127		)
	Net property, plant and equipment	$	1,433,313	$	829,346		Net property, plant and equipment	$	829,346		$	526,437
	Depreciation expense was $28.4 million and $13.7 million during the three months ended September 30, 2014 and 2013, respectively, and $46.9 million and $27.2 million during the six months ended September 30, 2014 and 2013, respectively.						Depreciation expense was $59.9 million, $39.2 million and $10.6 million during the years ended March 31, 2014, 2013 and 2012, respectively. During the year ended March 31, 2014, we capitalized $0.7 million of interest expense.
	Crude oil volumes required for the operation of storage tanks, known as tank bottoms, are recorded at historical cost. Tank bottoms are the volume of crude oil that must be maintained in a storage tank to enable operation of the storage tank. We recover tank bottom crude oil when we no longer use the storage tanks or the storage tanks are removed from service. At September 30, 2014, tank bottoms consisted of approximately 185,000 barrels.

Goodwill

Goodwill	12 Months Ended
	Mar. 31, 2014
Goodwill and Intangible Assets
Goodwill	Note 6 — Goodwill
	The changes in the balance of goodwill were as follows:
		Year Ended March 31,
		2014		2013		2012
		(in thousands)
	Beginning of period, as retrospectively adjusted (Note 2)	$	555,220	$	167,245	$	8,568
	Acquisitions	551,786		387,975		158,677
	End of period, as retrospectively adjusted (Note 2)	$	1,107,006	$	555,220	$	167,245
	Goodwill by reportable segment is as follows:
		March 31,
		2014		2013
		(in thousands)
	Crude oil logistics	$	606,383	$	246,345
	Water solutions	262,203		109,470
	Liquids	90,135		87,136
	Retail propane	114,285		112,269
	Refined products	22,000		—
	Renewables	12,000		—
		$	1,107,006	$	555,220

Intangible_Assets

Intangible Assets	12 Months Ended
	Mar. 31, 2014
Intangible Assets
Intangible Assets	Note 7 — Intangible Assets
	Our intangible assets consist of the following:
				March 31, 2014						March 31, 2013
										Gross Carrying
		Amortizable		Gross Carrying			Accumulated			Amount		Accumulated
		Lives		Amount			Amortization			(Note 2)		Amortization
							(in thousands)
	Amortizable -
	Customer relationships (1)	3–20 years		$	697,405		$	83,261		$	405,160	$	30,959
	Water facility development agreement	5 years		14,000			2,100			—		—
	Lease and other agreements	5–8 years		23,920			13,190			15,210		7,018
	Non-compete agreements	2–7 years		14,161			6,388			11,509		2,871
	Trade names	1–10 years		15,489			3,081			2,784		326
	Debt issuance costs	5–10 years		44,089			8,708			19,494		2,981
	Total amortizable			809,064			116,728			454,157		44,155
	Non-amortizable -
	Trade names			22,620						31,430
	Total			$	831,684		$	116,728		$	485,587	$	44,155
	(1)         The weighted-average remaining amortization period for customer relationship intangible assets is approximately nine years.
	Amortization expense was as follows:
		Year Ended March 31,
	Recorded in	2014			2013			2012
		(in thousands)
	Depreciation and amortization	$	60,855		$	29,657		$	4,538
	Cost of sales	6,172			5,285			800
	Interest expense	5,727			3,375			1,277
	Loss on early extinguishment of debt	—			5,769			—
		$	72,754		$	44,086		$	6,615
	Expected amortization of our intangible assets is as follows (in thousands):
	Year Ending March 31,
	2015	$	88,970
	2016	83,449
	2017	76,826
	2018	72,857
	2019	66,826
	Thereafter	303,408
		$	692,336

LongTerm_Obligations

Long-Term Obligations	6 Months Ended																12 Months Ended
	Sep. 30, 2014																Mar. 31, 2014
Long-Term Debt
Long-Term Obligations	Note 7 — Long-Term Debt																Note 8 — Long-Term Obligations
	Our long-term debt consists of the following:																Our long-term debt consists of the following:
		September 30,			March 31,													March 31,
		2014			2014													2014		2013
		(in thousands)																(in thousands)
	Revolving credit facility —																Revolving credit facility —
	Expansion capital borrowings	$	137,000		$	532,500											Expansion capital loans	$	532,500	$	441,500
	Working capital borrowings	942,500			389,500												Working capital loans	389,500		36,000
	5.125% Notes due 2019	400,000			—												Senior notes	250,000		250,000
	6.875% Notes due 2021	450,000			450,000												Unsecured notes	450,000		—
	6.650% Notes due 2022	250,000			250,000												Other notes payable	14,914		21,562
	TLP credit facility	252,000			—													1,636,914		749,062
	Other long-term debt	10,913			14,914
		2,442,413			1,636,914												Less - current maturities	7,080		8,626
	Less - current maturities	5,062			7,080												Long-term debt	$	1,629,834	$	740,436
	Long-term debt	$	2,437,351		$	1,629,834
																	Credit Agreement
	Credit Agreement
																	On June 19, 2012, we 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”).
	On June 19, 2012, we 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”).
																	The Working Capital Facility had a total capacity of $935.5 million for cash borrowings and letters of credit at March 31, 2014. At March 31, 2014, we had outstanding cash borrowings of $389.5 million and outstanding letters of credit of $270.6 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $785.5 million for cash borrowings at March 31, 2014. At March 31, 2014, we had outstanding cash borrowings of $532.5 million on the Expansion 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 Working Capital Facility had a total capacity of $1.335 billion for cash borrowings and letters of credit at September 30, 2014. At that date, we had outstanding borrowings of $942.5 million and outstanding letters of credit of $209.2 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $858.0 million for cash borrowings at September 30, 2014. At that date, we had outstanding borrowings of $137.0 million on the Expansion 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 pre-pay outstanding borrowings under the Credit Agreement without incurring any penalties, and pre-payments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings.
	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 (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At March 31, 2014, the interest rate in effect on outstanding LIBOR borrowings was 1.91%, calculated as the LIBOR rate of 0.16% plus a margin of 1.75%. At March 31, 2014, the interest rate in effect on letters of credit was 1.75%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At March 31, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
	All borrowings under the Credit Agreement bear interest, at our option, at (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At September 30, 2014, all borrowings under the Credit Agreement were LIBOR borrowings with an interest rate at September 30, 2014 of 1.91%, calculated as the LIBOR rate of 0.16% plus a margin of 1.75%. At September 30, 2014, the interest rate in effect on letters of credit was 2.00%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At September 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
																		Amount		Rate
		Amount			Rate												Expansion capital facility —
	Expansion Capital Facility —																LIBOR borrowings	$	532,500	1.91	%
	LIBOR borrowings	$	137,000		1.91	%											Working capital facility —
	Working Capital Facility —																LIBOR borrowings	358,000		1.91	%
	LIBOR borrowings	942,500			1.91	%											Base rate borrowings	31,500		4	%
	The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our leverage ratio, as defined in the Credit Agreement, cannot exceed 4.25 to 1 at any quarter end. At September 30, 2014, our leverage ratio was approximately 3.4 to 1. The Credit Agreement also specifies that our interest coverage ratio, as defined in the Credit Agreement, cannot be less than 2.75 to 1 at any quarter end. At September 30, 2014, our interest coverage ratio was approximately 4.8 to 1.																The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our “leverage ratio,” as defined in the Credit Agreement, cannot exceed 4.25 to 1.0 at any quarter end. At March 31, 2014, our leverage ratio was approximately 3 to 1. The Credit Agreement also specifies that our “interest coverage ratio,” as defined in the Credit Agreement, cannot be less than 2.75 to 1 as of the last day of any fiscal quarter. At March 31, 2014, our interest coverage ratio was approximately 7 to 1.
	The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.																The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.
	At September 30, 2014, we were in compliance with the covenants under the Credit Agreement.																At March 31, 2014, we were in compliance with the covenants under the Credit Agreement.
	2019 Notes																Senior Notes
	On July 9, 2014, we issued $400.0 million of 5.125% Senior Notes Due 2019 (the “2019 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 $393.5 million, after the initial purchasers’ discount of $6.0 million and estimated offering costs of $0.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.																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 “Senior Notes”). The Senior Notes have an aggregate principal amount of $250.0 million and bear interest at a fixed rate of 6.65%. Interest is payable quarterly. The Senior 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 pre-pay outstanding principal, although we would incur a pre-payment penalty. The Senior Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.
	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 prior to the maturity date, although we would be required to pay a premium for early redemption.																The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which are described above.
	The Partnership and NGL Energy Finance Corp. are co-issuers of the 2019 Notes, and the obligations under the 2019 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2019 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.																The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) non-payment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the Senior Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the Senior Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding Senior Notes of any series may declare all of the Senior Notes of such series to be due and payable immediately.
	At September 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2019 Notes.																At March 31, 2014, we were in compliance with the covenants under the Note Purchase Agreement and the Senior Notes.
	We also entered into a registration rights agreement whereby we have committed to exchange the 2019 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2019 Notes on or before July 9, 2015. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2019 Notes.																Unsecured Notes
	2021 Notes																On October 16, 2013, we issued $450.0 million of 6.875% senior unsecured notes (the “Unsecured 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 $438.4 million, after the initial purchasers’ discount of $10.1 million and estimated offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.
	On October 16, 2013, we issued $450.0 million of 6.875% Senior Notes Due 2021 (the “2021 Notes”) in a private placement exempt from registration under the Securities Act pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $438.4 million, after the initial purchasers’ discount of $10.1 million and offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.																The Unsecured 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 Unsecured Notes prior to the maturity date, although we would be required to pay a premium for early redemption.
	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 prior to the maturity date, although we would be required to pay a premium for early redemption.																The purchase agreement and the indenture governing the Unsecured Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.
	The Partnership and NGL Energy Finance Corp. are co-issuers of the 2021 Notes, and the obligations under the 2021 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2021 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.																At March 31, 2014, we were in compliance with the covenants under the Unsecured Notes.
	At September 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2021 Notes.																We also entered into a registration rights agreement whereby we have committed to exchange the Unsecured Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the Unsecured Notes on or before October 16, 2014. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the Unsecured Notes.
	We also entered into a registration rights agreement whereby we have committed to exchange the 2021 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2021 Notes on or before October 16, 2014. Our inability to register the notes on time may result in liquidated damages of approximately $0.1 million per month.																Other Notes Payable
	2022 Notes																We have executed various non-interest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. We also have certain notes payable related to equipment financing, which have interest rates ranging from 2.1% to 4.9% at March 31, 2014.
	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%. Interest 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. The 2022 Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.																Debt Maturity Schedule
	The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains substantially the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which is described above.																The scheduled maturities of our long-term debt are as follows at March 31, 2014:
	The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) nonpayment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the 2022 Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the 2022 Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding 2022 Notes of any series may declare all of the 2022 Notes of such series to be due and payable immediately.																	Revolving						Other
																		Credit		Senior		Unsecured		Notes
	At September 30, 2014, we were in compliance with the covenants under the Note Purchase Agreement.																Year Ending March 31,	Facility		Notes		Notes		Payable		Total
																						(in thousands)
	TLP Credit Facility																2015	$	—	$	—	$	—	$	7,081	$	7,081
																	2016	—		—		—		3,614		3,614
	On March 9, 2011, TLP entered into an amended and restated senior secured credit facility (“TLP Credit Facility”), which has been subsequently amended from time to time. The TLP Credit Facility provides for a maximum borrowing line of credit equal to the lesser of (i) $350 million and (ii) 4.75 times Consolidated EBITDA (as defined in the TLP Credit Facility: $352.9 million at September 30, 2014). TLP may elect to have loans under the TLP Credit Facility that bear interest either (i) at a rate of LIBOR plus a margin ranging from 2% to 3% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 1% to 2% depending on the total leverage ratio then in effect. TLP also pays a commitment fee on the unused amount of commitments, ranging from 0.375% to 0.50% per annum, depending on the total leverage ratio then in effect. TLP’s obligations under the TLP Credit Facility are secured by a first priority security interest in favor of the lenders in the majority of TLP assets.																2017	—		—		—		2,356		2,356
																	2018	—		25,000		—		1,449		26,449
	The terms of the TLP Credit Facility include covenants that restrict TLP’s ability to make cash distributions, acquisitions and investments, including investments in joint ventures. TLP may make distributions of cash to the extent of its “available cash” as defined in the TLP partnership agreement. TLP may make acquisitions and investments that meet the definition of “permitted acquisitions”; “other investments” which may not exceed 5% of “consolidated net tangible assets”; and “permitted JV investments”. Permitted JV investments include up to $225 million of investments in BOSTCO, the “Specified BOSTCO Investment”. In addition to the Specified BOSTCO Investment, under the terms of the TLP Credit Facility, TLP may make an additional $75 million of other permitted JV investments (including additional investments in BOSTCO). The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date, March 9, 2016.																2019	922,000		50,000		—		238		972,238
																	Thereafter	—		175,000		450,000		176		625,176
	The TLP Credit Facility also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). The primary financial covenants contained in the TLP Credit Facility are (i) a total leverage ratio test (not to exceed 4.75 times), (ii) a senior secured leverage ratio test (not to exceed 3.75 times) in the event TLP issues senior unsecured notes, and (iii) a minimum interest coverage ratio test (not less than 3.0 times).																	$	922,000	$	250,000	$	450,000	$	14,914	$	1,636,914
	If TLP were to fail any financial performance covenant, or any other covenant contained in the TLP Credit Facility, TLP would seek a waiver from its lenders under such facility. If TLP was unable to obtain a waiver from its lenders and the default remained uncured after any applicable grace period, TLP would be in breach of the TLP Credit Facility, and the lenders would be entitled to declare all outstanding borrowings immediately due and payable. TLP was in compliance with all of the financial covenants under the TLP Credit Facility as of September 30, 2014.																Previous Credit Facilities
	At September 30, 2014, TLP had $252.0 million of outstanding borrowings under the TLP Credit Facility and no outstanding letters of credit.																On June 19, 2012, we made a principal payment of $306.8 million to retire our previous revolving credit facility. Upon retirement of this facility, we wrote off the portion of the debt issuance cost asset that had not yet been amortized. This expense is reported as “Loss on early extinguishment of debt” in our consolidated statement of operations for the year ended March 31, 2013.
	The following table summarizes our basis in the assets and liabilities of TLP at September 30, 2014, inclusive of the impact of our acquisition accounting for the business combination with TransMontaigne (in thousands):
Cash and cash equivalents	$	726
Accounts receivable - trade, net	12,252
Accounts receivable - affiliates	1,105
Inventories	1,613
Prepaid expenses and other current assets	1,363
Property, plant and equipment, net	504,272
Goodwill	29,118
Intangible assets, net	38,571
Investments in unconsolidated entities	268,410
Other noncurrent assets	1,910
Accounts payable - trade	(4,009		)
Accounts payable - affiliates	(146		)
Accrued expenses and other payables	(11,625		)
Advanced payments received from customers	(141		)
Long-term debt	(252,000		)
Other noncurrent liabilities	(4,247		)
Net assets	$	587,172
Other Long-Term Debt
We have executed various noninterest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. We also have certain notes payable related to equipment financing.
Debt Maturity Schedule
The scheduled maturities of our long-term debt are as follows at September 30, 2014:
	Revolving									TLP		Other
	Credit			2019		2021		2022		Credit		Long-Term
Year Ending March 31,	Facility			Notes		Notes		Notes		Facility		Debt		Total
	(in thousands)
2015 (six months)	$	—		$	—	$	—	$	—	$	—	$	2,345	$	2,345
2016	—			—		—		—		252,000		3,128		255,128
2017	—			—		—		—		—		2,362		2,362
2018	—			—		—		25,000		—		1,459		26,459
2019	1,079,500			—		—		50,000		—		1,438		1,130,938
Thereafter	—			400,000		450,000		175,000		—		181		1,025,181
Total	$	1,079,500		$	400,000	$	450,000	$	250,000	$	252,000	$	10,913	$	2,442,413

Income_Taxes

Income Taxes	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Income Taxes
Income Taxes	Note 8 — Income Taxes	Note 9 — 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 believe that 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. We utilize the asset and liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply in the years in which these temporary differences are expected to be recovered or settled. Changes in tax rates are recognized in income in the period that includes the enactment date.	We have certain taxable corporate subsidiaries in the United States and Canada. In addition, our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales.
	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.	A publicly traded partnership is required to generate at least 90% of its gross income (as defined for federal income tax purposes) from certain qualifying sources. Income generated by our taxable corporate subsidiaries is excluded from this qualifying income calculation. Although we routinely generate income outside of our corporate subsidiaries that is non-qualifying, we believe that at least 90% of our gross income has been qualifying income for each of the calendar years since our IPO.
	We 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 the consolidated financial statements at September 30, 2014.	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 the consolidated financial statements at March 31, 2014.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Commitments and Contingencies
Commitments and Contingencies	Note 9 — Commitments and Contingencies					Note 10 — Commitments and Contingencies
	Legal 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, will not 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.					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, will not 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.
	Customer Dispute					Customer Dispute
	A customer of our crude oil logistics segment disputed the transportation rate schedule we used to bill the customer for services that we provided from November 2012 through February 2013, which was the same rate schedule that Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”), used to bill the customer from April 2011 through October 2012 (prior to our November 1, 2012 acquisition of Pecos). The customer disputed a portion of the amount we charged for services we provided from November 2012 through February 2013. In May 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. Later in May 2013, the customer filed an answer and counterclaim seeking to recover certain amounts that it paid to Pecos prior to our acquisition of Pecos.					A customer of our crude oil logistics segment has disputed the transportation rate schedule we used to bill the customer for services that we provided from November 2012 through February 2013, which was the same rate schedule that Pecos used to bill the customer from April 2011 through October 2012 (prior to our acquisition of Pecos). The customer has not paid $1.7 million of the amount we charged for services we provided from November 2012 through February 2013. In May 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. Later in May 2013, the customer filed an answer and counterclaim seeking to recover $5.5 million that it paid to Pecos prior to our acquisition of Pecos. We have not recorded revenue for the $1.7 million of unpaid fees charged from November 2012 through February 2013, pending resolution of the dispute.
	During August 2013, the customer notified us that it intended to withhold payment due for services performed by us during the period from June 2013 through August 2013, pending resolution of the dispute, although the customer did not dispute the validity of the amounts billed for services performed during this time frame. Upon receiving this notification, we ceased providing services under this contract, and on November 5, 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer.					During August 2013, the customer notified us that it intended to withhold payment of $3.3 million for services performed by us during the period from June 2013 through August 2013, pending resolution of the dispute, although the customer has not disputed the validity of the amounts billed for services performed during this time frame. Upon receiving this notification, we ceased providing services under this contract, and on November 5, 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. We are not able to reliably predict the outcome of this dispute at this time, but we do not believe the outcome will have a material adverse effect on our consolidated financial position or results of operations.
	During September 2014, we reached an agreement with the former customer whereby the former customer agreed to pay us an agreed-upon amount to dismiss its claims against us, in return for which we agreed to dismiss our other claims against the former customer. We did not record a gain or loss upon settlement, as the amount we received approximated the amount we had recorded as receivable from the customer.					Canadian Fuel and Sales Taxes
	Environmental Matters					The taxing authority of a province in Canada completed an audit of fuel and sales tax payments and alleged that an entity we acquired should have collected from customers and remitted to the taxing authority fuel and sales taxes on certain historical sales. We recorded in the acquisition accounting a liability of $0.8 million (net of receivables for expected recoveries from other parties). We now believe this matter is resolved, and we removed the liability from our consolidated balance sheet and recorded a corresponding reduction to cost of sales during the year ended March 31, 2014.
	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 significant costs will not be incurred. 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.					Environmental Matters
	Asset Retirement Obligations					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 significant costs will not be incurred. 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.
	We have recorded a liability of $2.7 million at September 30, 2014 for asset retirement obligations. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.					Asset Retirement Obligations
	In addition to the obligations described 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.					We have recorded a liability of $2.3 million at March 31, 2014 for asset retirement obligations. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.
	Operating Leases					In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. However, 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.
	We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, railcars, and equipment. Future minimum lease payments under these agreements at September 30, 2014 are as follows (in thousands):					Operating Leases
	Year Ending March 31,					We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, and equipment. Future minimum lease payments under contractual commitments at March 31, 2014 are as follows (in thousands):
	2015 (six months)	$	71,007
	2016	106,384				Year Ending March 31,
	2017	88,666				2015	$	133,170
	2018	74,265				2016	93,454
	2019	49,907				2017	64,209
	Thereafter	117,125				2018	49,802
	Total	$	507,354			2019	29,213
						Thereafter	58,182
	Rental expense relating to operating leases was $29.3 million and $23.6 million during the three months ended September 30, 2014 and 2013, respectively, and $54.6 million and $45.5 million during the six months ended September 30, 2014 and 2013, respectively.					Total	$	428,030
	Pipeline Capacity Agreements					Rental expense relating to operating leases was $98.3 million, $84.2 million, and $5.2 million during the years ended March 31, 2014, 2013, and 2012, respectively.
	We have executed noncancelable agreements with crude and refined products pipeline operators, which guarantee us minimum monthly shipping capacity on the pipelines. In exchange, we are obligated to pay the minimum shipping fees in the event actual shipments are less than our allotted capacity. Future minimum throughput payments under these agreements at September 30, 2014 are as follows (in thousands):					Sales and Purchase Contracts
	Year Ending March 31,					We have entered into sales and purchase contracts for products to be delivered in future periods for which we expect the parties to physically settle the contracts with inventory. At March 31, 2014, we had the following such commitments outstanding:
	2015 (six months)	$	41,822
	2016	95,050					Volume		Value
	2017	82,916					(in thousands)
	2018	62,565				Natural gas liquids fixed-price purchase commitments (gallons)	31,111		$	39,117
	2019	51,278				Natural gas liquids floating-price purchase commitments (gallons)	522,947		618,293
	Thereafter	107,537				Natural gas liquids fixed-price sale commitments (gallons)	63,944		77,682
	Total	$	441,168			Natural gas liquids floating-price sale commitments (gallons)	272,495		395,095
						Crude oil fixed-price purchase commitments (barrels)	4,016		364,557
	Sales and Purchase Contracts					Crude oil fixed-price sale commitments (barrels)	3,574		324,765
	We have entered into sales and purchase contracts for products to be delivered in future periods for which we expect the parties to physically settle the contracts with inventory. At September 30, 2014, we had the following such commitments outstanding:
						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 (described in Note 12) or inventory positions (described in Note 2).
		Volume		Value
		(in thousands)				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 on our consolidated balance sheet and are not included in the data in the table above. These contracts are included in the derivative disclosures in Note 12, and represent $43.5 million of our prepaid expenses and other current assets and $34.6 million of our accrued expenses and other payables at March 31, 2014.
	Natural gas liquids fixed-price purchase commitments (gallons)	88,574		$	102,000
	Natural gas liquids index-price purchase commitments (gallons)	528,459		601,719
	Natural gas liquids fixed-price sale commitments (gallons)	278,391		351,137
	Natural gas liquids index-price sale commitments (gallons)	370,639		512,900
	Crude oil index-price purchase commitments (barrels)	4,437		383,153
	Crude oil fixed-price sale commitments (barrels)	32		2,867
	Crude oil index-price sale commitments (barrels)	3,920		337,528
	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 (described in Note 11) or inventory positions (described in Note 2).
	Certain other forward purchase and sale contracts do not qualify for the normal purchase and normal sale election. These contracts are recorded at fair value on our condensed consolidated balance sheet and are not included in the table above. These contracts are included in the derivative disclosures in Note 11, and represent $44.4 million of our prepaid expenses and other current assets and $36.3 million of our accrued expenses and other payables at September 30, 2014.

Equity

Equity	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Equity
Equity	Note 10 — Equity												Note 11 — Equity
	Partnership 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. Prior to August 2014, the Partnership’s limited partner interest also included subordinated units. The subordination period ended in August 2014, at which time all remaining subordinated units were converted into common units on a one-for-one basis.												The Partnership’s equity consists of a 0.1% general partner interest and a 99.9% limited partner interest. Limited partner equity includes common and subordinated units. The common and subordinated units share equally in the allocation of income or loss. The principal difference between common and subordinated units is that in any quarter during the subordination period, holders of the subordinated units are not entitled to receive any distribution until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units will not accrue arrearages.
	Our general partner is not obligated to make any additional capital contributions or to guarantee or pay any of our debts and obligations.												We expect the subordination period to end in August 2014. When the subordination period ends, all remaining subordinated units will convert into common units on a one-for-one basis and the common units will no longer be entitled to arrearages.
	Equity Issuances												Our general partner is not obligated to make any additional capital contributions or to guarantee or pay any of our debts and obligations.
	On June 23, 2014, we completed a public offering of 8,000,000 common units. We received net proceeds of $338.0 million, after underwriting discounts and commissions of $12.3 million and offering costs of $0.5 million. During July 2014, the underwriters exercised their option to purchase an additional 767,100 units, from which we received net proceeds of $32.4 million.												Initial Public Offering
	Distributions to Owners												On May 17, 2011, we completed our IPO. We sold a total of 4,025,000 common units in our IPO at $21.00 per unit. Our proceeds from the sale of 3,850,000 common units of $71.9 million, net of total offering costs of $9.0 million, were used to repay advances under our acquisition credit facility and for general partnership purposes. Proceeds from the sale of 175,000 common units ($3.4 million) from the underwriters’ exercise of their option to purchase additional common units from us were used to redeem 175,000 of the common units outstanding prior to our IPO. Upon the completion of our IPO and the underwriters’ exercise in full of their option to purchase additional common units from us and the redemption, we had outstanding 8,864,222 common units, 5,919,346 subordinated units, a 0.1% general partner interest, and IDRs.
	Our general partner has adopted a cash distribution policy that requires us to pay a quarterly distribution to unitholders as of the record date to the extent we have sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner and its affiliates, referred to as “available cash.” The general partner will also receive, in addition to distributions on its 0.1% general partner interest, additional distributions based on the level of distributions to the limited partners. These distributions are referred to as “incentive distributions.” Our general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in our partnership agreement.												Common Units Issued in Business Combinations
	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest In Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit,” until available cash from operating surplus we distribute reaches the next target distribution level, if any. The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 0.1% general partner interest, assume our general partner has contributed any additional capital necessary to maintain its 0.1% general partner interest and has not transferred its incentive distribution rights.												As described in Note 4, we issued common units as partial consideration for several acquisitions. These are summarized below:
									Marginal Percentage Interest In				Osterman combination	4,000,000
		Total Quarterly							Distributions				SemStream combination	8,932,031
		Distribution Per Unit							Unitholders		General Partner		Pacer combination	1,500,000
	Minimum quarterly distribution						$	0.3375	99.9	%	0.1	%	Total - Year Ended March 31, 2012	14,432,031
	First target distribution	above		$	0.3375	up to	$	0.388125	99.9	%	0.1	%
	Second target distribution	above		$	0.388125	up to	$	0.421875	86.9	%	13.1	%	High Sierra combination	20,703,510
	Third target distribution	above		$	0.421875	up to	$	0.50625	76.9	%	23.1	%	Retail propane combinations	850,676
	Thereafter	above		$	0.50625				51.9	%	48.1	%	Crude oil logistics and water solutions combinations	516,978
													Pecos combination	1,834,414
	During the three months ended September 30, 2014, we distributed a total of $61.5 million ($0.5888 per common, subordinated, and general partner notional unit) to our unitholders of record on August 4, 2014, which included an incentive distribution of $9.5 million to the general partner. In October 2014, we declared a distribution of $0.6088 per common unit, to be paid on November 14, 2014 to unitholders of record on November 4, 2014. This distribution is expected to be $65.0 million, including amounts to be paid on common and general partner notional units and the amount to be paid on incentive distribution rights.												Third Coast combination	344,680
													Total - Year Ended March 31, 2013	24,250,258
	Distributions to Noncontrolling Interest Partners
													Water solutions combinations	222,381
	TLP’s general partner has adopted a cash distribution policy that requires it to pay a quarterly distribution to unitholders as of the record date to the extent TLP has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to TLP’s general partner and its affiliates, referred to as “available cash.” TLP’s general partner will also receive, in addition to distributions on its 2.0% general partner interest, additional distributions based on the level of distributions to the limited partners. These distributions are referred to as “incentive distributions.” TLP’s general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in TLP’s partnership agreement.												Crude oil logistics combinations	175,211
													OWL combination	2,463,287
	The following table illustrates the percentage allocations of available cash from operating surplus between TLP’s unitholders and TLP’s general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest In Distributions” are the percentage interests of TLP’s general partner and TLP’s unitholders in any available cash from operating surplus TLP distributes up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit,” until available cash from operating surplus TLP distributes reaches the next target distribution level, if any. The percentage interests shown for TLP’s unitholders and TLP’s general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for TLP’s general partner include its 2.0% general partner interest, assume TLP’s general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and has not transferred its incentive distribution rights.												Total - Year Ended March 31, 2014	2,860,879
									Marginal Percentage Interest In				In connection with the completion of certain of these transactions, we amended our Registration Rights Agreement, which provides for certain registration rights for certain holders of our common units.
		Total Quarterly							Distributions
		Distribution Per Unit							Unitholders		General Partner		Equity Issuances
	Minimum quarterly distribution						$	0.4	98	%	2	%
	First target distribution	above		$	0.4	up to	$	0.44	98	%	2	%	On July 5, 2013, we completed a public offering of 10,350,000 common units. We received net proceeds of $287.5 million, after underwriting discounts and commissions of $12.0 million and offering costs of $0.7 million.
	Second target distribution	above		$	0.44	up to	$	0.5	85	%	15	%
	Third target distribution	above		$	0.5	up to	$	0.6	75	%	25	%	On September 25, 2013, we completed a public offering of 4,100,000 common units. We received net proceeds of $127.6 million, after underwriting discounts and commissions of $5.0 million and offering costs of $0.2 million.
	Thereafter	above		$	0.6				50	%	50	%
													On December 2, 2013, we issued and sold 8,110,848 of our common units in a private placement. We received net proceeds of $235.1 million, after offering costs of $4.9 million.
	During the three months ended September 30, 2014, TLP declared and paid a distribution of $0.665 per unit. The noncontrolling interest owners received a total of $8.7 million from this distribution. Pursuant to the terms of the agreement related to our acquisition of TransMontaigne, we remitted the amount we received on this distribution on our general partner interest, incentive distribution rights, and limited partner interest to the former owners of TransMontaigne.
													Distributions
	In October 2014, TLP declared a distribution of $0.665 per unit, which was paid on November 7, 2014. The noncontrolling interest owners received a total of $8.7 million from this distribution.
													Our general partner has adopted a cash distribution policy that will require us to pay a quarterly distribution to the extent we have sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner and its affiliates, referred to as “available cash,” in the following manner:
	Equity-Based Incentive Compensation
													·                  First, 99.9% to the holders of common units and 0.1% to the general partner, until each common unit has received the specified minimum quarterly distribution, plus any arrearages from prior quarters.
	Our general partner has adopted a long-term incentive plan (“LTIP”), which allows for the issuance of equity-based compensation to employees and directors. Our general partner has granted certain restricted units to employees and directors, which will 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. No distributions will accrue to or be paid on the restricted units during the vesting period.
													·                  Second, 99.9% to the holders of subordinated units and 0.1% to the general partner, until each subordinated unit has received the specified minimum quarterly distribution.
	The following table summarizes the restricted unit activity during the six months ended September 30, 2014:
													·                  Third, 99.9% to all unitholders, pro rata, and 0.1% to the general partner.
	Unvested restricted units at March 31, 2014	1,311,100
	Units granted	333,903											The general partner will also receive, in addition to distributions on its 0.1% general partner interest, additional distributions based on the level of distributions paid to the limited partners. These distributions are referred to as “incentive distributions.”
	Units vested and issued	(438,009	)
	Units withheld for employee taxes	(231,194	)										The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 0.1% general partner interest, assume our general partner has contributed any additional capital necessary to maintain its 0.1% general partner interest and has not transferred its IDRs and there are no arrearages on common units.
	Units forfeited	(117,000	)
	Unvested restricted units at September 30, 2014	858,800																			Marginal Percentage Interest In
														Total Quarterly							Distributions
	The scheduled vesting of our unvested restricted units is summarized below:													Distribution per Unit							Unitholders		General Partner
													Minimum quarterly distribution						$ 0.337500		99.9	%	0.1	%
	Vesting Date	Number of Awards											First target distribution	above		$ 0.337500	up to		$ 0.388125		99.9	%	0.1	%
	July 1, 2015	334,800											Second target distribution	above		$ 0.388125	up to		$ 0.421875		86.9	%	13.1	%
	July 1, 2016	314,000											Third target distribution	above		$ 0.421875	up to		$ 0.506250		76.9	%	23.1	%
	July 1, 2017	178,500											Thereafter	above		$ 0.506250					51.9	%	48.1	%
	July 1, 2018	31,500
	Unvested restricted units at September 30, 2014	858,800											On May 5, 2011, we made a distribution of $3.9 million from available cash to our general partner and common unitholders at March 31, 2011.
	We record the expense for the first tranche of each award on a straight-line basis over the period beginning with the grant date of the awards and ending with the vesting date of the tranche. We record the expense for succeeding tranches over the period beginning with the vesting date of the previous tranche and ending with the vesting date of the tranche.												The following table summarizes the distributions declared subsequent to our IPO:
	At each balance sheet date, we adjust the cumulative expense recorded using the estimated fair value of the awards at the balance sheet date. We calculate the fair value of the awards using the closing price of our common units on the New York Stock Exchange on the balance sheet date, adjusted to reflect the fact that the holders of the unvested units are not entitled to distributions during the vesting period. We estimate the impact of the lack of distribution rights during the vesting period using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.																Amount			Amount Paid to			Amount Paid to
													Date Declared	Record Date		Date Paid	Per Unit			Limited Partners			General Partner
	We recorded expense related to restricted unit awards of $13.8 million and $3.2 million during the three months ended September 30, 2014 and 2013, respectively, and $21.7 million and $10.3 million during the six months ended September 30, 2014 and 2013, respectively. We estimate that the future expense we will record on the unvested awards at September 30, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of approximately 80,000 units. For purposes of this calculation, we used the closing price of our common units on September 30, 2014, which was $39.37.																			(in thousands)			(in thousands)
													July 25, 2011	August 3, 2011		August 12, 2011	$	0.1669		$	2,467		$	3
Year Ending March 31,												October 21, 2011	October 31, 2011		November 14, 2011	0.3375			4,990			5
2015 (six months)	$	6,343										January 24, 2012	February 3, 2012		February 14, 2012	0.35			7,735			10
2016	11,516											April 18, 2012	April 30, 2012		May 15, 2012	0.3625			9,165			10
2017	7,262											July 24, 2012	August 3, 2012		August 14, 2012	0.4125			13,574			134
2018	2,237											October 17, 2012	October 29, 2012		November 14, 2012	0.45			22,846			707
2019	249											January 24, 2013	February 4, 2013		February 14, 2013	0.4625			24,245			927
Total	$	27,607										April 25, 2013	May 6, 2013		May 15, 2013	0.4775			25,605			1,189
												July 25, 2013	August 5, 2013		August 14, 2013	0.4938			31,725			1,739
Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our condensed consolidated balance sheets (in thousands):												October 23, 2013	November 4, 2013		November 14, 2013	0.5113			35,908			2,491
												January 23, 2014	February 4, 20143		February 14, 2014	0.5313			42,150			4,283
Balance at March 31, 2014	$	10,012										April 24, 2014	May 5, 2014		May 15, 2014	0.5513			43,737			5,754
Expense recorded	21,659
Value of units vested and issued	(18,763		)
Taxes paid on behalf of participants	(9,901		)									Several of our business combination agreements contained provisions that temporarily limited the distributions to which the newly-issued units were entitled. The following table summarizes the number of equivalent units that were not eligible to receive a distribution on each of the record dates:
Balance at September 30, 2014	$	3,007
													Equivalent
The weighted-average fair value of the awards at September 30, 2014 was $35.16 per common unit, which was calculated as the closing price of the common units on September 30, 2014, adjusted to reflect the fact that the restricted units are not entitled to distributions during the vesting period. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.													Units Not
												Record Date	Eligible
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 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 will not be considered to be delivered under the LTIP. In addition, if 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, 2014, 7.1 million units remain available for issuance under the LTIP.												August 3, 2011	—
												October 31, 2011	4,000,000
												February 3, 2012	7,117,031
												April 30, 2012	3,932,031
												August 3, 2012	17,862,470
												October 29, 2012	516,978
												February 4, 2013	1,202,085
												May 6, 2013	—
												August 5, 2013	—
												November 4, 2013	979,886
												February 4, 2014	—
												May 5, 2014	—
												Equity-Based Incentive Compensation
												Our general partner has adopted a long-term incentive plan (“LTIP”) which allows for the issuance of equity-based compensation to employees and directors. The board of directors of our general partner has granted certain restricted units to employees and directors, which will 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. No distributions will accrue to or be paid on the restricted units during the vesting period.
												The following table summarizes the restricted unit activity during the years ended March 31, 2014 and 2013:
												Unvested restricted units at March 31, 2012	—
												Units granted	1,684,400
												Units vested and issued	(156,802	)
												Units withheld for employee taxes	(61,698	)
												Units forfeited	(21,000	)
												Unvested restricted units at March 31, 2013	1,444,900
												Units granted	494,000
												Units vested and issued	(296,269	)
												Units withheld for employee taxes	(122,531	)
												Units forfeited	(209,000	)
												Unvested restricted units at March 31, 2014	1,311,100
												The scheduled vesting of the awards is summarized below:
												Vesting Date	Number of Awards
												July 1, 2014	408,300
												January 1, 2015	4,000
												July 1, 2015	341,300
												January 1, 2016	4,000
												July 1, 2016	322,500
												January 1, 2017	4,000
												July 1, 2017	192,500
												January 1, 2018	4,000
												July 1, 2018	30,500
												Total unvested units at March 31, 2014	1,311,100
												We record the expense for each tranche on a straight-line basis over the period beginning with the vesting of the previous tranche and ending with the vesting of the tranche. We adjust the cumulative expense recorded through the reporting date using the estimated fair value of the awards at the reporting date. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth. We estimate that the future expense we will record on the unvested awards at March 31, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of 95,000 units. For purposes of this calculation, we have used the closing price of the common units on March 31, 2014, which was $37.53.
												Year Ending March 31,
												2015	$	14,393
												2016	11,279
												2017	7,429
												2018	2,310
												2019	229
												Total	$	35,640
												Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our consolidated balance sheets (in thousands):
												Balance at March 31, 2012	$	—
												Expense recorded	10,138
												Value of units vested and issued	(3,627		)
												Taxes paid on behalf of participants	(1,468		)
												Balance at March 31, 2013	5,043
												Expense recorded	17,804
												Value of units vested and issued	(9,085		)
												Taxes paid on behalf of participants	(3,750		)
												Balance at March 31, 2014	$	10,012
												The weighted-average fair value of the awards at March 31, 2014 was $33.78, which was calculated as the closing price of the common units on March 31, 2014, adjusted to reflect the fact that the restricted units are not entitled to distributions during the vesting period. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.
												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 and subordinated units. The maximum number of units deliverable under the plan automatically increases to 10% of the issued and outstanding common and subordinated 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, if 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 March 31, 2014, 6.2 million units remain available for issuance under the LTIP.

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Fair Value of Financial Instruments
Fair Value of Financial Instruments	Note 11 — Fair Value of Financial Instruments												Note 12 — 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.												Our cash and cash equivalents, accounts receivable, accounts payable, accrued expenses, and other current liabilities (excluding derivative instruments) are carried at amounts which reasonably approximate their fair values, due to their short-term nature. We believe the carrying amounts of our long-term debt instruments, including the Revolving Credit Facility and the Senior Notes, approximate their fair values, as we do not believe market conditions have changed materially since we entered into these debt agreements.
	Commodity Derivatives												Commodity Derivatives
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at September 30, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2014:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	48,632		$	(5,378	)					Level 1 measurements	$	4,990		$	(3,258	)
	Level 2 measurements		51,389			(38,280		)					Level 2 measurements	49,605			(43,303		)
			100,021			(43,658		)						54,595			(46,561		)
	Netting of counterparty contracts (1)		(4,635		)	4,635							Netting of counterparty contracts(1)	(4,347		)	4,347
	Cash collateral held		(13,704		)	—							Cash collateral provided or held	456			—
	Commodity derivatives on condensed consolidated balance sheet		$	81,682		$	(39,023	)					Commodity contracts reported on consolidated balance sheet	$	50,704		$	(42,214	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at March 31, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2013:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	4,990		$	(3,258	)					Level 1 measurements	$	947		$	(3,324	)
	Level 2 measurements		49,605			(43,303		)					Level 2 measurements	9,911			(13,280		)
			54,595			(46,561		)						10,858			(16,604		)
	Netting of counterparty contracts (1)		(4,347		)	4,347							Netting of counterparty contracts(1)	(3,503		)	3,503
	Net cash collateral provided		456			—							Cash collateral provided or held	(1,760		)	400
	Commodity derivatives on condensed consolidated balance sheet		$	50,704		$	(42,214	)					Commodity contracts reported on consolidated balance sheet	$	5,595		$	(12,701	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	Our commodity derivative assets and liabilities are reported in the following accounts on the condensed consolidated balance sheets:												The commodity derivative assets (liabilities) are reported in the following accounts on the consolidated balance sheets:
			September 30,			March 31,								March 31,
			2014			2014								2014			2013
			(in thousands)											(in thousands)
	Prepaid expenses and other current assets		$	81,682		$	50,704						Prepaid expenses and other current assets	$	50,704		$	5,551
	Accrued expenses and other payables		(39,023		)	(42,214		)					Other noncurrent assets	—			44
	Net commodity derivative asset		$	42,659		$	8,490						Accrued expenses and other payables	(42,214		)	(12,701		)
													Net asset (liability)	$	8,490		$	(7,106	)
	The following table summarizes our open commodity derivative contract positions at September 30, 2014 and March 31, 2014. We do not account for these derivatives as hedges.
													The following table sets forth our open commodity derivative contract positions at March 31, 2014 and 2013. We do not account for these derivatives as hedges.
					Total		Fair Value
					Notional		of						Contracts	Settlement Period		Total		Fair Value
					Units		Net Assets									Notional		of Net Assets
	Contracts		Settlement Period		(Barrels)		(Liabilities)									Units		(Liabilities)
					(in thousands)											(Barrels)
	At September 30, 2014 -															(in thousands)
	Cross-commodity (1)		October 2014 – March 2015		(12	)	$	(1,283	)				At March 31, 2014 -
	Crude oil fixed-price (2)		October 2014 – December 2015		(1,638	)	9,380						Cross-commodity (1)	April 2014 – March 2015		140		$	(1,876	)
	Crude oil index (3)		October 2014 – July 2015		2,195		4,397						Crude oil fixed-price (2)	April 2014 – March 2015		(1,600	)	(2,796		)
	Propane fixed-price (4)		October 2014 – March 2015		1,238		53						Crude oil index (3)	April 2014 – December 2015		3,598		6,099
	Refined products fixed-price (5)		October 2014 – July 2015		(4,475	)	38,712						Propane fixed-price (4)	April 2014 – March 2015		60		1,753
	Renewable products fixed-price (6)		October 2014 – December 2015		(14	)	5,104						Refined products fixed-price (5)	April 2014 – July 2014		732		560
							56,363						Renewable products fixed-price (6)	April 2014 – July 2014		106		4,084
	Net cash collateral held						(13,704		)				Other	April 2014		—		210
	Net commodity derivatives on condensed consolidated balance sheet						$	42,659										8,034
													Net cash collateral provided					456
	At March 31, 2014 -												Net value of commodity derivatives on consolidated balance sheet					$	8,490
	Cross-commodity (1)		April 2014 – March 2015		140		$	(1,876	)
	Crude oil fixed-price (2)		April 2014 – March 2015		(1,600	)	(2,796		)				At March 31, 2013 -
	Crude oil index (3)		April 2014 – December 2015		3,598		6,099						Cross-commodity (1)	April 2013 - March 2014		430		$	(10,208	)
	Propane fixed-price (4)		April 2014 – March 2015		60		1,753						Crude oil fixed-price (2)	April 2013 - March 2014		(144	)	1,033
	Refined products fixed-price (5)		April 2014 – July 2014		732		560						Crude oil index (3)	April 2013 - June 2014		(91	)	153
	Renewable products fixed-price (6)		April 2014 – July 2014		106		4,084						Propane fixed-price (4)	April 2013 - March 2014		(282	)	3,197
	Other		April 2014		—		210						Other	May 2013 - June 2013		8		79
							8,034											(5,746		)
	Net cash collateral provided						456						Net cash collateral held					(1,360		)
	Net commodity derivatives on condensed consolidated balance sheet						$	8,490					Net value of commodity derivatives on consolidated balance sheet					$	(7,106	)
	(1)     Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price.												(1)         Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as economic hedges against the risk of one commodity price moving relative to another commodity price.
	(2)     Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.												(2)         Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
(3)     Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.												(3)         Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
(4)     Propane fixed-price — Our liquids segment routinely purchases propane inventory during the warmer months and stores the propane inventory for sale during the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.												(4)         Propane fixed-price — Our liquids segment routinely purchases inventory during the warmer months and stores the inventory for sale in the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
(5)     Refined products fixed-price — Our refined products and renewables segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.												(5)         Refined products fixed-price — Our refined products segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
(6)     Renewable products fixed-price — Our refined products and renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.												(6)         Renewable products fixed-price — Our renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
We recorded the following net gains (losses) from our commodity derivatives to cost of sales:												We recorded the following net gains (losses) from our commodity derivatives to cost of sales:
Three Months Ended						Six Months Ended						Year Ended March 31,
September 30,						September 30,						2014	$	(43,655	)
2014			2013			2014			2013			2013	(4,381		)
(in thousands)												2012	5,676
$	55,981		$	(10,672	)	$	38,496		$	(17,881	)
												Credit Risk
Credit Risk
												We maintain credit policies with regard to our counterparties on the derivative financial instruments 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 standardized agreements, which allow for netting of positive and negative exposure associated with a single counterparty.
We maintain credit policies with regard to our counterparties on the derivative financial instruments 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 standardized agreements, which allow for netting of positive and negative exposure associated with a single counterparty.
												We may enter into industry standard master netting agreements and may enter into cash collateral agreements requiring the counterparty to deposit funds into a brokerage margin account. The netting agreements reduce our credit risk by providing for net settlement of any offsetting positive and negative exposures with counterparties. The cash collateral agreements reduce the level of our net counterparty credit risk because the amount of collateral represents additional funds that we may access to net settle positions due us, and the amount of collateral adjusts each day in response to changes in the market value of counterparty derivatives.
We may enter into industry standard master netting agreements and may enter into cash collateral agreements requiring the counterparty to deposit funds into a brokerage margin account. The netting agreements reduce our credit risk by providing for net settlement of any offsetting positive and negative exposures with counterparties. The cash collateral agreements reduce the level of our net counterparty credit risk because the amount of collateral represents additional funds that we may access to net settle positions due us, and the amount of collateral adjusts each day in response to changes in the market value of counterparty derivatives.
												Our counterparties consist primarily of financial institutions and energy companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
Our counterparties consist primarily of financial institutions and energy companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
												As is customary in the crude oil industry, we generally receive payment from customers on a monthly basis. As a result, receivables from individual customers in our crude oil logistics are typically higher than the receivables from customers of our other segments.
As is customary in the crude oil industry, we generally receive payment from customers for sales of crude oil on a monthly basis. As a result, receivables from individual customers in our crude oil logistics segment are generally higher than the receivables from customers in our other segments.
												Failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our consolidated statements of financial position and recognized in our net income.
Failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our condensed consolidated balance sheets and recognized in our net income.
												Interest Rate Risk
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 March 31, 2014, we have $922.0 million of outstanding borrowings under our Revolving Credit Facility at a rate of 1.98%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $1.2 million on the $922.0 million of outstanding borrowings on the revolving credit facility at March 31, 2014.
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, 2014, we had $1.1 billion of outstanding borrowings under our Revolving Credit Facility at a rate of 1.91%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $1.3 million, based on borrowings outstanding at September 30, 2014.
The TLP Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At September 30, 2014, TLP had $252.0 million of outstanding borrowings under the TLP Credit Facility at a rate of 2.66%. A change in interest rates of 0.125% would result in an increase or decrease in TLP’s annual interest expense of $0.3 million, based on borrowings outstanding at September 30, 2014.
Fair Value of Notes
The following table provides estimates of the fair values of our fixed-rate notes at September 30, 2014 (in thousands):
5.125% Notes due 2019		$	390,000
6.875% Notes due 2021		475,000
6.650% Notes due 2022		275,000
For the 2019 Notes and the 2021 Notes, the fair value estimates were developed by reference to broker quotes.  These estimates would be classified as Level 2 in the fair value hierarchy. For the 2022 Notes, the estimate was developed using observed yields on publicly-traded notes issued by other entities, 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).  These estimates of fair value would be classified as Level 3 in the fair value hierarchy.

Segments

Segments	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Segments
Segments	Note 12 — Segments													Note 13 — Segments
	Our reportable segments are based on the way in which our management structure is organized. Certain financial data related to our segments is shown below. Transactions between segments are recorded based on prices negotiated between the segments.													Our reportable segments are based on the way in which our management structure is organized. Certain financial data related to our segments is shown below. Transactions between segments are recorded based on prices negotiated between the segments.
	Our crude oil logistics segment sells crude oil and provides crude oil transportation services to wholesalers, refiners, and producers. Our water solutions segment provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production, and generates revenue from the sale of recycled water and recovered hydrocarbons. Our liquids segment supplies propane, butane, and other products, and provides natural gas liquids transportation, terminaling, and storage services to retailers, wholesalers, and refiners. Our retail propane segment sells propane and distillates to end users consisting of residential, agricultural, commercial, and industrial customers, and to certain re-sellers. Our retail propane segment consists of two divisions, which are organized based on the location of the operations. Our refined products and renewables segment provides integrated terminaling, storage, transportation, marketing, and related services for companies engaged in the trading, distribution and marketing of refined petroleum products, ethanol, and biodiesel. This segment began with our December 2013 acquisition of Gavilon Energy and expanded with our July 2014 acquisition of TransMontaigne.													Our crude oil logistics segment sells crude oil and provides crude oil transportation services to wholesalers, refiners, and producers. Our water solutions segment provides services for the transportation, treatment, and disposal of wastewater generated from crude oil and natural gas production, and generates revenue from the sale of recycled wastewater and recovered hydrocarbons. Our liquids segment supplies propane, butane, and other products, and provides natural gas liquids transportation, terminaling, and storage services to retailers, wholesalers, and refiners. Our retail propane segment sells propane and distillates to end users consisting of residential, agricultural, commercial, and industrial customers, and to certain re-sellers. Our retail propane segment consists of two divisions, which are organized based on the location of the operations.
	Items labeled “corporate and other” in the table below include the operations of a compressor leasing business that we sold in February 2014 and certain natural gas marketing operations that we acquired in our December 2013 acquisition of Gavilon Energy and wound down during fiscal year 2014. The “corporate and other” category also includes certain corporate expenses that are incurred and are not allocated to the reportable segments. This data is included to reconcile the data for the reportable segments to data in our condensed consolidated financial statements.													We also operate a refined products marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities. We also operate a renewables business, which purchases ethanol primarily at production facilities, and transports the ethanol for sale at various locations to refiners and blenders, and purchases biodiesel from production facilities in the Midwest and in Houston, Texas, and transports the product using leased railcars for sale to refiners and blenders. These businesses were acquired in our December 2013 acquisition of Gavilon Energy.
		Three Months Ended						Six Months Ended						Items labeled “corporate and other” in the table below include the operations of a compressor leasing business that we acquired in our June 2012 merger with High Sierra and sold in February 2014, and the natural gas marketing operations that we acquired in our December 2013 acquisition of Gavilon Energy and began winding down during fiscal 2014. The “corporate and other” category also includes certain corporate expenses that are incurred and are not allocated to the reportable segments. This data is included to reconcile the data for the reportable segments to data in our consolidated financial statements.
		September 30,						September 30,
		2014			2013			2014			2013			Certain information related to the results of operations of each segment is shown in the tables below:
		(in thousands)
	Revenues:														Year Ended March 31,
	Crude oil logistics -														2014			2013			2012
	Crude oil sales	$	2,108,117		$	1,013,061		$	4,035,061		$	1,941,595			(in thousands)
	Crude oil transportation and other	13,082			9,794			25,196			19,729			Revenues:
	Water solutions -													Crude oil logistics -
	Water treatment and disposal	47,572			28,823			89,288			47,511			Crude oil sales	$	4,559,923		$	2,322,706		$	—
	Water transportation	5,147			5,367			10,745			7,192			Crude oil transportation and other	36,469			16,442			—
	Liquids -													Water solutions -
	Propane sales	240,433			191,437			462,879			315,274			Water treatment and disposal	125,788			54,334			—
	Other product sales	306,625			308,606			594,984			558,459			Water transportation	17,312			7,893			—
	Other revenues	6,814			9,250			12,530			18,114			Liquids -
	Retail propane -													Propane sales	1,632,948			841,448			923,022
	Propane sales	48,552			40,651			100,578			87,342			Other product sales	1,231,965			858,276			251,627
	Distillate sales	11,530			10,562			30,225			28,431			Other revenues	31,062			33,954			2,462
	Other revenues	8,276			8,198			15,457			15,898			Retail propane -
	Refined products and renewables -													Propane sales	388,225			288,410			175,417
	Refined products sales	2,489,795			—			3,476,018			—			Distillate sales	127,672			106,192			6,547
	Renewables sales	117,425			—			248,699			—			Other revenues	35,918			35,856			17,370
	Corporate and other	1,333			1,485			2,794			2,959			Refined products	1,180,895			—			—
	Elimination of intersegment sales	(24,175		)	(33,297		)	(75,314		)	(62,610		)	Renewables	176,781			—			—
	Total revenues	$	5,380,526		$	1,593,937		$	9,029,140		$	2,979,894		Corporate and other	437,713			4,233			—
														Eliminations of intersegment sales	(283,397		)	(151,977		)	(65,972		)
	Depreciation and Amortization:													Total revenues	$	9,699,274		$	4,417,767		$	1,310,473
	Crude oil logistics	$	9,240		$	3,330		$	18,971		$	8,014
	Water solutions	17,573			11,438			34,665			18,794				Year Ended March 31,
	Liquids	3,384			2,672			6,585			5,376				2014			2013			2012
	Retail propane	7,684			6,871			15,255			14,111				(in thousands)
	Refined products and renewables	11,917			—			12,761			—			Depreciation and amortization:
	Corporate and other	301			750			1,237			1,490			Crude oil logistics	$	22,111		$	9,176		$	—
	Total depreciation and amortization	$	50,099		$	25,061		$	89,474		$	47,785		Water solutions	55,105			20,923			—
														Liquids	11,018			11,085			3,661
	Operating Income (Loss):													Retail propane	28,878			25,496			11,450
	Crude oil logistics	$	38		$	5,884		$	1,501		$	12,493		Refined products	109			—			—
	Water solutions	14,792			2,913			13,885			5,956			Renewables	516			—			—
	Liquids	10,929			14,605			10,016			12,490			Corporate and other	3,017			2,173			—
	Retail propane	(3,062		)	(4,520		)	(4,648		)	(6,024		)	Total depreciation and amortization	$	120,754		$	68,853		$	15,111
	Refined products and renewables	8,822			—			7,567			—
	Corporate and other	(23,749		)	(8,937		)	(41,106		)	(22,312		)		Year Ended March 31,
	Total operating income (loss)	$	7,770		$	9,945		$	(12,785	)	$	2,603			2014			2013			2012
															(in thousands)
	The following table summarizes additions to property, plant and equipment for each segment. This information has been prepared on the accrual basis, and includes property, plant and equipment acquired in acquisitions.													Operating income (loss):
														Crude oil logistics	$	678		$	34,236		$	—
		Three Months Ended						Six Months Ended						Water solutions	10,317			8,576			—
		September 30,						September 30,						Liquids	71,888			30,336			9,735
		2014			2013			2014			2013			Retail propane	61,285			46,869			9,616
		(in thousands)												Refined products	4,080			—			—
	Additions to property, plant and equipment:													Renewables	2,434			—			—
	Crude oil logistics	$	39,464		$	31,336		$	81,413		$	35,462		Corporate and other	(44,117		)	(32,710		)	(4,321		)
	Water solutions	40,610			62,473			48,072			70,182			Total operating income	$	106,565		$	87,307		$	15,030
	Liquids	1,911			13,209			3,070			28,316
	Retail propane	9,567			4,546			12,411			11,492			The table below shows additions to property, plant and equipment for each segment. This information has been prepared on the accrual basis, and includes property, plant and equipment acquired in acquisitions.
	Refined products and renewables	512,281			—			512,281			—
	Corporate and other	1,809			217			3,262			846				Year Ended March 31,
	Total	$	605,642		$	111,781		$	660,509		$	146,298			2014			2013			2012
															(in thousands)
	The following tables summarize long-lived assets (consisting of net property, plant and equipment, net intangible assets, and goodwill) and total assets by segment:													Additions to property, plant and equipment, including acquisitions (accrual basis):
													Crude oil logistics	$	204,642		$	89,860		$	—
	September 30,			March 31,									Water solutions	100,877			137,116			—
	2014			2014									Liquids	52,560			15,129			50,276
	(in thousands)												Retail propane	24,430			66,933			150,181
Total assets:													Refined products	719			—			—
Crude oil logistics	$	2,079,380		$	1,723,812								Renewables	519			—			—
Water solutions	964,336			875,714									Corporate and other	7,242			17,858			—
Liquids	756,133			577,795									Total	$	390,989		$	326,896		$	200,457
Retail propane	506,958			541,832
Refined products and renewables	2,183,674			303,230									The following tables show long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment:
Corporate and other	61,198			144,840
Total	$	6,551,679		$	4,167,223									March 31,
																	2013
Long-lived assets, net:														2014			(Note 2)
Crude oil logistics	$	996,615		$	980,978									(in thousands)
Water solutions	910,467			848,479									Total assets:
Liquids	271,567			274,846									Crude oil logistics	$	1,723,812		$	801,351
Retail propane	436,621			438,324									Water solutions	875,714			466,412
Refined products and renewables	772,916			60,720									Liquids	577,795			474,141
Corporate and other	53,705			47,961									Retail propane	541,832			513,301
Total	$	3,441,891		$	2,651,308								Refined products	157,581			—
													Renewables	145,649			—
													Corporate and other	144,840			36,413
													Total	$	4,167,223		$	2,291,618
													Long-lived assets, net:
													Crude oil logistics	$	980,978		$	357,230
													Water solutions	848,479			453,909
													Liquids	274,846			238,192
													Retail propane	438,324			441,762
													Refined products	27,017			—
													Renewables	33,703			—
													Corporate and other	47,961			31,996
													Total	$	2,651,308		$	1,523,089

Disposals_and_Impairments

Disposals and Impairments	12 Months Ended
	Mar. 31, 2014
Disposals and Impairments
Disposals and Impairments	Note 14 — Disposals and Impairments
	We acquired Gavilon Energy in December 2013, which operated a natural gas marketing business. During March 2014, we assigned all of the storage and transportation contracts of the natural gas marketing business to a third party. Since these contracts were at unfavorable terms relative to current market conditions, we paid $44.8 million to assign these contracts. We recorded a liability of $50.8 million related to these storage and transportation contracts in the acquisition accounting, and we amortized $6.0 million of this balance through cost of sales during the period from the acquisition date through the date we assigned the contracts. We also assigned all forward purchase and sale contracts and all financial derivative contracts, and thereby wound down the natural gas business. Our consolidated statement of operations for the year ended March 31, 2014 includes $1.4 million of operating income related to the natural gas business, which is reported within “corporate and other” in the segment disclosures in Note 13.
	We acquired High Sierra in June 2012, which operated a compressor leasing business. We sold the compressor leasing business in February 2014 for $10.8 million (net of the amount due to the owner of the noncontrolling interest in the business). We recorded a gain on the sale of the business of $4.4 million, $1.6 million of which was attributable to the disposal of the noncontrolling interest. We reported the gain as a reduction to operating expenses in our consolidated statement of operations. Our consolidated statement of operations for the year ended March 31, 2014 includes $2.3 million of operating income related to the compressor leasing business, which is reported within “corporate and other” in the segment disclosures in Note 13.
	During the year ended March 31, 2014, we recorded an impairment of $5.3 million to the property, plant and equipment of one of our natural gas liquids terminals. This loss is reported within operating expenses of our liquids segment.
	During the year ended March 31, 2014, two of our water solutions facilities experienced damage to their property, plant and equipment as a result of lightning strikes. We recorded a write-down to property, plant and equipment of $1.5 million related to these incidents, which is reported within operating expenses in our consolidated statement of operations.

Transactions_with_Affiliates

Transactions with Affiliates	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Transactions with Affiliates
Transactions with Affiliates	Note 13 — Transactions with Affiliates									Note 15 — Transactions with Affiliates
	SemGroup Corporation (“SemGroup”) holds ownership interests in us and in our general partner. We sell product to and purchase product from SemGroup, and these transactions are included within revenues and cost of sales in our condensed consolidated statements of operations. We also lease crude oil storage from SemGroup.									Since our business combination with SemStream on November 1, 2011, SemGroup Corporation (“SemGroup”) has held ownership interests in us and in our general partner, and has the right to appoint two members to the board of directors of our general partner. Subsequent to November 1, 2011, we have sold product to and purchased product from affiliates of SemGroup. These transactions are included within revenues and cost of sales in our consolidated statements of operations.
	We purchase ethanol from one of our equity method investees. These transactions are reported within cost of sales in our condensed consolidated statements of operations.									Certain members of our management own interests in entities with which we have purchased products and services from and have sold products and services. The majority of these purchases represent crude oil purchases and are reported within cost of sales in our consolidated statements of operations, although $8.2 million of these transactions during the year ended March 31, 2014 represented capital expenditures and were recorded as increases to property, plant and equipment. The majority of these sales represent sales of crude oil and have been recorded within revenues in our consolidated statement of operations.
	Certain members of our management own interests in entities from which we have purchased products and services and to which we have sold products and services to. The majority of these purchases represented crude oil purchases and are reported within cost of sales in our condensed consolidated statements of operations, although $5.8 million of these transactions during the six months ended September 30, 2014 represented capital expenditures and were recorded as increases to property, plant and equipment. The majority of these sales represented crude oil sales and are reported within revenues in our condensed consolidated statements of operations.									These transactions are summarized in the table below:
	The above transactions are summarized in the following table:										Year Ended March 31,
											2014		2013		2012
		Three Months Ended				Six Months Ended					(in thousands)
		September 30,				September 30,				Sales to SemGroup	$	306,780	$	32,431	$	29,200
		2014		2013		2014		2013		Purchases from SemGroup	445,951		60,425		23,800
		(in thousands)								Sales to entities affiliated with management	110,824		16,828		—
	Sales to SemGroup	$	43,427	$	3,780	$	117,233	$	3,780	Purchases from entities affiliated with management	120,038		60,942		—
	Purchases from SemGroup	45,730		28,377		118,997		47,916
	Purchases from equity method investees	34,689		—		70,965		—
	Sales to equity method investees	9,131		—		9,131		—		Receivables from affiliates consist of the following:
	Sales to entities affiliated with management	1,706		58,769		1,854		109,872
	Purchases from entities affiliated with management	3,845		48,522		6,984		56,346			March 31,
											2014		2013
											(in thousands)
	Receivables from affiliates consist of the following:									Receivables from entities affiliated with management	$	142	$	22,883
										Receivables from SemGroup	7,303		—
		September 30,		March 31,							$	7,445	$	22,883
		2014		2014
		(in thousands)								Payables to affiliates consist of the following:
	Receivables from SemGroup	$	39,331	$	7,303
	Receivables from entities affiliated with management	1,705		142							March 31,
	Receivables from equity method investees	670		—							2014		2013
	Total	$	41,706	$	7,445						(in thousands)
										Payables to SemGroup	$	76,192	$	4,601
	Payables to affiliates consist of the following:									Payables to entities affiliated with management	654		2,299
											$	76,846	$	6,900
		September 30,		March 31,
		2014		2014						We completed a merger with High Sierra Energy, LP and High Sierra Energy GP, LLC in June 2012. We paid $91.8 million of cash, net of $5.0 million of cash acquired, and issued 18,018,468 common units to acquire High Sierra Energy, LP. We also paid $97.4 million of High Sierra Energy, LP’s long-term debt and other obligations. Our general partner acquired High Sierra Energy GP, LLC by paying $50.0 million of cash and issuing equity. Our general partner then contributed its ownership interests in High Sierra Energy GP, LLC to us, in return for which we paid our general partner $50.0 million of cash and issued 2,685,042 common units to our general partner.
		(in thousands)
	Payables to SemGroup	$	44,015	$	27,738					During the year ended March 31, 2014, we completed the acquisition of a crude oil logistics business owned by an employee. We paid $11.0 million of cash for this acquisition. During the year ended March 31, 2013, we completed two business combinations with entities in which members of our management owned interests. We paid $14.0 million of cash (net of cash acquired) on a combined basis for these two acquisitions. We also paid $5.0 million under a non-compete agreement to an employee.
	Payables to equity method investees	39,549		48,454
	Payables to entities affiliated with management	1,743		654
	Total	$	85,307	$	76,846

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Mar. 31, 2014
Quarterly Financial Data (Unaudited)
Quarterly Financial Data (Unaudited)	Note 16 — Quarterly Financial Data (Unaudited)
	Our summarized unaudited quarterly financial data is presented below. The computation of net income per common and subordinated unit is done separately by quarter and year. The total of net income per common and subordinated unit of the individual quarters may not equal the net income per common and subordinated unit for the year, due primarily to the income allocation between the general partner and limited partners and variations in the weighted average units outstanding used in computing such amounts.
	Our retail propane segment’s business is seasonal due to weather conditions in our service areas. Propane sales to residential and commercial customers are affected by winter heating season requirements, which generally results in higher operating revenues and net income during the period from October through March of each year and lower operating revenues and either net losses or lower net income during the period from April through September of each year. Our liquids segment is also subject to seasonal fluctuations, as demand for propane and butane is typically higher during the winter months. Our operating revenues from our other segments are less weather sensitive. Additionally, the acquisitions described in Note 4 impact the comparability of the quarterly information within the year, and year to year.
		Quarter Ended										Year Ended
		June 30,			September 30,			December 31,		March 31,		March 31,
		2013			2013			2013		2014		2014
		(in thousands, except unit and per unit data)
	Total revenues	$	1,385,957		$	1,593,937		$	2,743,445	$	3,975,935	$	9,699,274
	Total cost of sales	$	1,303,076		$	1,488,850		$	2,576,029	$	3,764,744	$	9,132,699
	Net income (loss)	$	(17,508	)	$	(932	)	$	24,052	$	43,146	$	48,758
	Net income (loss) attributable to parent equity	$	(17,633	)	$	(941	)	$	23,898	$	42,331	$	47,655
	Earnings (loss) per unit, basic and diluted -
	Common units	$	(0.35	)	$	(0.05	)	$	0.27	$	0.46	$	0.51
	Subordinated units	$	(0.46	)	$	(0.09	)	$	0.23	$	0.46	$	0.32
	Weighted average common units outstanding - basic and diluted	47,703,313			58,909,389			67,941,726		73,421,309		61,970,471
	Weighted average subordinated outstanding units - basic and diluted	5,919,346			5,919,346			5,919,346		5,919,346		5,919,346
		Quarter Ended										Year Ended
		June 30,			September 30,			December 31,		March 31,		March 31,
		2012			2012			2012		2013		2013
		(in thousands, except unit and per unit data)
	Total revenues	$	326,436		$	1,135,510		$	1,338,208	$	1,617,613	$	4,417,767
	Total cost of sales	$	298,985		$	1,053,690		$	1,204,545	$	1,481,890	$	4,039,110
	Net income (loss)	$	(24,710	)	$	10,082		$	40,477	$	22,341	$	48,190
	Net income (loss) attributable to parent equity	$	(24,650	)	$	10,073		$	40,176	$	22,341	$	47,940
	Earnings (loss) per unit, basic and diluted -
	Common units	$	(0.76	)	$	0.18		$	0.75	$	0.39	$	0.96
	Subordinated units	$	(0.77	)	$	0.18		$	0.75	$	0.39	$	0.93
	Weighted average common units outstanding - basic and diluted	26,529,133			44,831,836			46,364,381		47,665,015		41,353,574
	Weighted average subordinated outstanding units - basic and diluted	5,919,346			5,919,346			5,919,346		5,919,346		5,919,346

Condensed_Consolidating_Guaran

Condensed Consolidating Guarantor and Non-Guarantor Financial Information	6 Months Ended																			12 Months Ended
	Sep. 30, 2014																			Mar. 31, 2014
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Condensed Consolidating Guarantor and Non-Guarantor Financial Information	Note 14 — Condensed Consolidating Guarantor and Non-Guarantor Financial Information																			Note 17 — 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 the 2021 Notes (described in Note 7). 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, NGL Energy Finance Corp. (which, along with NGL Energy Partners LP, is a co-issuer of the 2019 Notes and 2021 Notes), the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis in the tables below.																			Certain of our wholly-owned subsidiaries have, jointly and severally, fully and unconditionally guaranteed the Unsecured Notes (described in 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, NGL Energy Finance Corp. (which, along with NGL Energy Partners LP, is a co-issuer of the Unsecured Notes), the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis 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.																			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 Unsecured Notes. Such changes have been given retrospective application in the tables below.
	There are no significant restrictions upon the ability of the parent or any of the guarantor subsidiaries to obtain funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.																			There are no significant restrictions upon the ability of the parent or any of the guarantor subsidiaries to obtain funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.
	For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, not a business segment basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to or from consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating cash flow tables below.																			For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, not a business segment basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to or from consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating cash flow tables below.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Balance Sheet																			Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		September 30, 2014																			March 31, 2014
		NGL Energy			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
		Partners LP																			Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	ASSETS																			ASSETS
	CURRENT ASSETS:																			CURRENT ASSETS:
	Cash and cash equivalents	$	2,841		$	—		$	7,823		$	1,159		$	—		$	11,823		Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			1,419,442			13,675			—			1,433,117			Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904
	Accounts receivable - affiliates	—			—			41,035			671			—			41,706			Accounts receivable - affiliates	—			—			7,445			—			—			7,445
	Inventories	—			—			937,814			3,775			—			941,589			Inventories	—			—			306,434			3,726			—			310,160
	Prepaid expenses and other current assets	—			—			155,332			1,486			—			156,818			Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	2,841			—			2,561,446			20,766			—			2,585,053			Total current assets	1,181			—			1,290,690			17,428			—			1,309,299
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			863,694			569,619			—			1,433,313			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346
	GOODWILL	—			—			1,139,374			31,116			—			1,170,490			GOODWILL	—			—			1,105,008			1,998			—			1,107,006
	INTANGIBLE ASSETS, net of accumulated amortization	1,307			17,619			778,960			40,202			—			838,088			INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956
	INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			214,234			268,410			—			482,644			INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821
	NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893			849,526			(1,026,605		)	(71,814		)	—			—			NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—
	INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573			—			10,470			—			(1,754,043		)	—			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
	OTHER NONCURRENT ASSETS	—			—			40,035			2,056			—			42,091			OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795
	Total assets	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679		Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	LIABILITIES AND EQUITY																			LIABILITIES AND EQUITY
	CURRENT LIABILITIES:																			CURRENT LIABILITIES:
	Accounts payable - trade	$	—		$	—		$	1,333,780		$	11,244		$	—		$	1,345,024		Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211
	Accounts payable - affiliates	—			—			85,237			70			—			85,307			Accounts payable - affiliates	—			—			73,703			3,143			—			76,846
	Accrued expenses and other payables	554			19,021			186,226			12,681			—			218,482			Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690
	Advance payments received from customers	—			—			105,597			508			—			106,105			Advance payments received from customers	—			—			29,891			74			—			29,965
	Current maturities of long-term debt	—			—			5,004			58			—			5,062			Current maturities of long-term debt	—			—			7,058			22			—			7,080
	Total current liabilities	554			19,021			1,715,844			24,561			—			1,759,980			Total current liabilities	554			14,266			961,827			19,145			—			995,792
	LONG-TERM DEBT, net of current maturities	250,000			850,000			1,085,155			252,196			—			2,437,351			LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834
	OTHER NONCURRENT LIABILITIES	—			—			35,160			4,358			—			39,518			OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744
																				EQUITY
	EQUITY																			Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815
	Partners’ equity (deficit)	1,746,060			(1,876		)	1,745,450			579,312			(2,322,813		)	1,746,133			Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
	Accumulated other comprehensive loss	—			—			(1		)	(72		)	—			(73		)	Noncontrolling interests	—			—			—			—			5,274			5,274
	Noncontrolling interests	—			—			—			—			568,770			568,770			Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
	Total equity (deficit)	1,746,060			(1,876		)	1,745,449			579,240			(1,754,043		)	2,314,830			Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	Total liabilities and equity	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679
																				(1)   The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)         The parent is a co-issuer of the 2019 Notes and 2021 Notes that are included in the NGL Energy Finance Corp. column.																			NGL ENERGY PARTNERS LP
																				Condensed Consolidating Balance Sheet
	NGL ENERGY PARTNERS LP																			(U.S. Dollars in Thousands)
	Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																				March 31, 2013
																					NGL Energy
		March 31, 2014																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		NGL Energy																			(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						ASSETS
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			CURRENT ASSETS:
	ASSETS																			Cash and cash equivalents	$	—		$	11,206		$	355		$	—		$	11,561
	CURRENT ASSETS:																			Accounts receivable - trade, net of allowance for doubtful accounts	—			561,560			1,197			—			562,757
	Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440		Accounts receivable - affiliates	—			22,883			—			—			22,883
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904			Inventories	—			126,024			871			—			126,895
	Accounts receivable - affiliates	—			—			7,445			—			—			7,445			Prepaid expenses and other current assets	—			37,784			107			—			37,891
	Inventories	—			—			306,434			3,726			—			310,160			Total current assets	—			759,457			2,530			—			761,987
	Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	1,181			—			1,290,690			17,428			—			1,309,299			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			497,743			28,694			—			526,437
																			GOODWILL	—			553,222			1,998			—			555,220
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346			INTANGIBLE ASSETS, net of accumulated amortization	717			439,365			1,350			—			441,432
GOODWILL	—			—			1,105,008			1,998			—			1,107,006			NET INTERCOMPANY RECEIVABLES (PAYABLES)	237,736			(233,294		)	(4,442		)	—			—
INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	895,779			20,371			—			(916,150		)	—
INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821			OTHER NONCURRENT ASSETS	—			6,542			—			—			6,542
NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—			Total assets	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795			LIABILITIES AND EQUITY
Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		CURRENT LIABILITIES:
																			Accounts payable - trade	$	—		$	534,164		$	1,891		$	—		$	536,055
LIABILITIES AND EQUITY																			Accounts payable - affiliates	—			6,900			—			—			6,900
CURRENT LIABILITIES:																			Accrued expenses and other payables	554			83,001			2,051			—			85,606
Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211		Advance payments received from customers	—			22,364			8			—			22,372
Accounts payable - affiliates	—			—			73,703			3,143			—			76,846			Current maturities of long-term debt	—			8,610			16			—			8,626
Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690			Total current liabilities	554			655,039			3,966			—			659,559
Advance payments received from customers	—			—			29,891			74			—			29,965
Current maturities of long-term debt	—			—			7,058			22			—			7,080			LONG-TERM DEBT, net of current maturities	250,000			490,433			3			—			740,436
Total current liabilities	554			14,266			961,827			19,145			—			995,792			OTHER NONCURRENT LIABILITIES	—			2,155			50			—			2,205
																			EQUITY
LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834			Partners’ equity	883,678			895,779			26,087			(921,890		)	883,654
OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744			Accumulated other comprehensive income	—			—			24			—			24
																			Noncontrolling interests	—			—			—			5,740			5,740
EQUITY																			Total equity	883,678			895,779			26,111			(916,150		)	889,418
Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815			Total liabilities and equity	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
Noncontrolling interests	—			—			—			—			5,274			5,274			NGL ENERGY PARTNERS LP
Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853			Condensed Consolidating Statement of Operations
Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		(U.S. Dollars in Thousands)
																				Year Ended March 31, 2014
(1)     The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.																				NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
NGL ENERGY PARTNERS LP																				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)																			REVENUES	$	—		$	—		$	9,560,124		$	139,519		$	(369	)	$	9,699,274
	Three Months Ended September 30, 2014																		COST OF SALES	—			—			9,011,011			122,057			(369		)	9,132,699
	NGL Energy
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						OPERATING COSTS AND EXPENSES:
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			Operating	—			—			253,214			6,182			—			259,396
																			General and administrative	—			—			77,756			2,104			—			79,860
REVENUES	$	—		$	—		$	5,325,186		$	55,364		$	(24	)	$	5,380,526		Depreciation and amortization	—			—			117,573			3,181			—			120,754
COST OF SALES	—			—			5,161,935			17,554			(24		)	5,179,465			Operating Income	—			—			100,570			5,995			—			106,565
OPERATING COSTS AND EXPENSES:																			OTHER INCOME (EXPENSE):
Operating	—			—			84,300			17,253			—			101,553			Earnings from unconsolidated entities	—			—			1,898			—			—			1,898
General and administrative	—			—			36,360			5,279			—			41,639			Interest expense	(16,818		)	(15,000		)	(27,031		)	(51		)	46			(58,854		)
Depreciation and amortization	—			—			38,999			11,100			—			50,099			Other, net	—			—			202			(70		)	(46		)	86
Operating Income	—			—			3,592			4,178			—			7,770			Income (Loss) Before Income Taxes	(16,818		)	(15,000		)	75,639			5,874			—			49,695
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			—			(937		)	—			—			(937		)
Earnings of unconsolidated entities	—			—			2,310			1,387			—			3,697
Interest expense	(4,067		)	(13,134		)	(9,956		)	(1,506		)	12			(28,651		)	EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	64,473			—			4,771			—			(69,244		)	—
Other, net	—			—			(524		)	(81		)	(12		)	(617		)
																			Net Income (Loss)	47,655			(15,000		)	79,473			5,874			(69,244		)	48,758
Income (Loss) Before Income Taxes	(4,067		)	(13,134		)	(4,578		)	3,978			—			(17,801		)
																			NET INCOME ALLOCATED TO GENERAL PARTNER													(14,148		)	(14,148		)
INCOME TAX (PROVISION) BENEFIT	—			—			1,951			(29		)	—			1,922
																			NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(1,103		)	(1,103		)
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(15,157		)	—			604			—			14,553			—
																			NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(84,495	)	$	33,507
Net Income (Loss)	(19,224		)	(13,134		)	(2,023		)	3,949			14,553			(15,879		)
																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(11,056		)	(11,056		)
																			NGL ENERGY PARTNERS LP
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,345		)	(3,345		)	Condensed Consolidating Statement of Operations
																			(U.S. Dollars in Thousands)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	152		$	(30,280	)
																				Year Ended March 31, 2013
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																				NGL Energy
																				Partners LP			Guarantor			Non-Guarantor			Consolidating
NGL ENERGY PARTNERS LP																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)																			REVENUES	$	—		$	4,409,198		$	8,878		$	(309	)	$	4,417,767
	Three Months Ended September 30, 2013																		COST OF SALES	—			4,038,251			1,168			(309		)	4,039,110
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor			Consolidating									OPERATING COSTS AND EXPENSES:
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Operating	—			164,944			4,855			—			169,799
																			General and administrative	—			52,461			237			—			52,698
REVENUES	$	—		$	1,546,226		$	47,735		$	(24	)	$	1,593,937					Depreciation and amortization	—			66,916			1,937			—			68,853
COST OF SALES	—			1,445,442			43,432			(24		)	1,488,850						Operating Income	—			86,626			681			—			87,307
OPERATING COSTS AND EXPENSES:																			OTHER INCOME (EXPENSE):
Operating	—			52,979			2,790			—			55,769						Interest expense	(13,041		)	(19,951		)	(48		)	46			(32,994		)
General and administrative	—			14,089			223			—			14,312						Loss on early extinguishment of debt	—			(5,769		)	—			—			(5,769		)
Depreciation and amortization	—			23,970			1,091			—			25,061						Other, net	—			1,666			(99		)	(46		)	1,521
Operating Income	—			9,746			199			—			9,945						Income (Loss) Before Income Taxes	(13,041		)	62,572			534			—			50,065
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			(1,875		)	—			—			(1,875		)
Interest expense	(4,179		)	(6,880		)	(13		)	12			(11,060		)
Other, net	—			528			(97		)	(12		)	419						EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	60,981			284			—			(61,265		)	—
Income (Loss) Before Income Taxes	(4,179		)	3,394			89			—			(696		)				Net Income	47,940			60,981			534			(61,265		)	48,190
INCOME TAX PROVISION	—			(236		)	—			—			(236		)				NET INCOME ALLOCATED TO GENERAL PARTNER										(2,917		)	(2,917		)
EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	3,238			80			—			(3,318		)	—						NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(250		)	(250		)
Net Income (Loss)	(941		)	3,238			89			(3,318		)	(932		)				NET INCOME ALLOCATED TO LIMITED PARTNERS	$	47,940		$	60,981		$	534		$	(64,432	)	$	45,023
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(2,451		)	(2,451		)				NGL ENERGY PARTNERS LP
																			Condensed Consolidating Statement of Operations
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(9		)	(9		)				(U.S. Dollars in Thousands)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(941	)	$	3,238		$	89		$	(5,778	)	$	(3,392	)					Year Ended March 31, 2012
																				NGL Energy
NGL ENERGY PARTNERS LP																				Partners LP			Guarantor			Non-Guarantor			Consolidating
Condensed Consolidating Statement of Operations																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
(U.S. Dollars in Thousands)
																			REVENUES	$	—		$	1,310,473		$	225		$	(225	)	$	1,310,473
	Six Months Ended September 30, 2014
	NGL Energy																		COST OF SALES	—			1,217,248			—			(225		)	1,217,023
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			OPERATING COSTS AND EXPENSES:
																			Operating	—			47,162			138			—			47,300
REVENUES	$	—		$	—		$	8,952,772		$	76,421		$	(53	)	$	9,029,140		General and administrative	—			15,823			186			—			16,009
																			Depreciation and amortization	—			14,964			147			—			15,111
COST OF SALES	—			—			8,676,881			36,690			(53		)	8,713,518
																			Operating Income (Loss)	—			15,276			(246		)	—			15,030
OPERATING COSTS AND EXPENSES:
Operating	—			—			150,919			18,502			—			169,421			OTHER INCOME (EXPENSE):
General and administrative	—			—			64,124			5,388			—			69,512			Interest expense	—			(7,619		)	(46		)	45			(7,620		)
Depreciation and amortization	—			—			77,545			11,929			—			89,474			Other, net	—			1,100			—			(45		)	1,055
Operating Income (Loss)	—			—			(16,697		)	3,912			—			(12,785		)	Income (Loss) Before Income Taxes	—			8,757			(292		)	—			8,465
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			(601		)	—			—			(601		)
Earnings of unconsolidated entities	—			—			4,875			1,387			—			6,262
Interest expense	(8,313		)	(21,280		)	(18,058		)	(1,517		)	23			(49,145		)	EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	7,876			(280		)	—			(7,596		)	—
Other, net	—			—			(1,056		)	71			(23		)	(1,008		)
																			Net Income (Loss)	7,876			7,876			(292		)	(7,596		)	7,864
Income (Loss) Before Income Taxes	(8,313		)	(21,280		)	(30,936		)	3,853			—			(56,676		)
																			NET INCOME ALLOCATED TO GENERAL PARTNER										(8		)	(8		)
INCOME TAX (PROVISION) BENEFIT	—			—			993			(106		)	—			887
																			NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS										12			12
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(50,886		)	—			337			—			50,549			—
																			NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	7,876		$	7,876		$	(292	)	$	(7,592	)	$	7,868
Net Income (Loss)	(59,199		)	(21,280		)	(29,606		)	3,747			50,549			(55,789		)
																			NGL ENERGY PARTNERS LP
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(20,437		)	(20,437		)	Condensed Consolidating Statements of Comprehensive Income (Loss)
																			(U.S. Dollars in Thousands)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,410		)	(3,410		)
																				Year Ended March 31, 2014
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	26,702		$	(79,636	)		NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
																				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
																			Net income (loss)	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(69,244	)	$	48,758
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Operations																			Other comprehensive loss, net of tax	—			—			(189		)	(71		)	—			(260		)
(U.S. Dollars in Thousands)
																			Comprehensive income (loss)	$	47,655		$	(15,000	)	$	79,284		$	5,803		$	(69,244	)	$	48,498
	Six Months Ended September 30, 2013
	NGL Energy																		(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	Partners LP			Guarantor			Non-Guarantor			Consolidating
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated							Year Ended March 31, 2013
																				NGL Energy
REVENUES	$	—		$	2,914,531		$	65,421		$	(58	)	$	2,979,894						Partners LP			Guarantor			Non-Guarantor			Consolidating
																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
COST OF SALES	—			2,735,890			56,094			(58		)	2,791,926
																			Net income	$	47,940		$	60,981		$	534		$	(61,265	)	$	48,190
OPERATING COSTS AND EXPENSES:
Operating	—			99,710			5,104			—			104,814						Other comprehensive loss, net of tax	—			—			(7		)	—			(7		)
General and administrative	—			32,297			469			—			32,766
Depreciation and amortization	—			46,000			1,785			—			47,785						Comprehensive income	$	47,940		$	60,981		$	527		$	(61,265	)	$	48,183
Operating Income	—			634			1,969			—			2,603							Year Ended March 31, 2012
																				NGL Energy
OTHER INCOME (EXPENSE):																				Partners LP			Guarantor			Non-Guarantor			Consolidating
Interest expense	(8,368		)	(13,309		)	(28		)	23			(21,682		)					(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Other, net	—			627			(135		)	(23		)	469
																			Net income (loss)	$	7,876		$	7,876		$	(292	)	$	(7,596	)	$	7,864
Income (Loss) Before Income Taxes	(8,368		)	(12,048		)	1,806			—			(18,610		)
																			Other comprehensive loss, net of tax	—			—			(25		)	—			(25		)
INCOME TAX BENEFIT	—			170			—			—			170
																			Comprehensive income (loss)	$	7,876		$	7,876		$	(317	)	$	(7,596	)	$	7,839
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(10,206		)	1,672			—			8,534			—
																			NGL ENERGY PARTNERS LP
Net Income (Loss)	(18,574		)	(10,206		)	1,806			8,534			(18,440		)				Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(4,139		)	(4,139		)
																				Year Ended March 31, 2014
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(134		)	(134		)					NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(18,574	)	$	(10,206	)	$	1,806		$	4,261		$	(22,713	)					(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated
																			OPERATING ACTIVITIES:
NGL ENERGY PARTNERS LP																			Net cash provided by (used in) operating activities	$	(16,625	)	$	—		$	99,754		$	2,107		$	85,236
Condensed Consolidating Statements of Comprehensive Income (Loss)
(U.S. Dollars in Thousands)																			INVESTING ACTIVITIES:
																			Purchases of long-lived assets	—			—			(118,455		)	(46,693		)	(165,148		)
	Three Months Ended September 30, 2014																		Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,154		)	—			(932,373		)	(2,283		)	(1,268,810		)
	NGL Energy																		Cash flows from commodity derivatives	—			—			(35,956		)	—			(35,956		)
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						Proceeds from sales of assets	—			—			12,884			11,776			24,660
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			Investments in unconsolidated entities	—			—			(11,515		)	—			(11,515		)
																			Distributions of capital from unconsolidated entities	—			—			1,591			—			1,591
Net income (loss)	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	14,553		$	(15,879	)	Other	—			—			540			(735		)	(195		)
																			Net cash used in investing activities	(334,154		)	—			(1,083,284		)	(37,935		)	(1,455,373		)
Other comprehensive income (loss)	—			—			4			(26		)	—			(22		)
																			FINANCING ACTIVITIES:
Comprehensive income (loss)	$	(19,224	)	$	(13,134	)	$	(2,019	)	$	3,923		$	14,553		$	(15,901	)	Proceeds from borrowings under revolving credit facilities	—			—			2,545,500			—			2,545,500
																			Payments on revolving credit facilities	—			—			(2,101,000		)	—			(2,101,000		)
																			Issuances of notes	—			450,000			—			—			450,000
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Proceeds from borrowings on other long-term debt	—			—			780			100			880
																			Payments on other long-term debt	—			—			(8,802		)	(17		)	(8,819		)
	Three Months Ended September 30, 2013																		Debt issuance costs	(645		)	(12,286		)	(11,664		)	—			(24,595		)
	NGL Energy																		Contributions	765			—			—			2,060			2,825
	Partners LP			Guarantor			Non-Guarantor			Consolidating									Distributions	(145,090		)	—			—			(840		)	(145,930		)
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Proceeds from sale of common units, net of offering costs	650,155			—			—			—			650,155
																			Net changes in advances with consolidated entities	(153,225		)	(437,714		)	556,238			34,701			—
Net income (loss)	$	(941	)	$	3,238		$	89		$	(3,318	)	$	(932	)				Net cash provided by financing activities	351,960			—			981,052			36,004			1,369,016
																			Net increase (decrease) in cash and cash equivalents	1,181			—			(2,478		)	176			(1,121		)
Other comprehensive loss	—			—			(5		)	—			(5		)				Cash and cash equivalents, beginning of period	—			—			11,206			355			11,561
																			Cash and cash equivalents, end of period	$	1,181		$	—		$	8,728		$	531		$	10,440
Comprehensive income (loss)	$	(941	)	$	3,238		$	84		$	(3,318	)	$	(937	)
																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
NGL ENERGY PARTNERS LP
Condensed Consolidating Statements of Comprehensive Income (Loss)																			NGL ENERGY PARTNERS LP
(U.S. Dollars in Thousands)																			Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2014
	NGL Energy																			Year Ended March 31, 2013
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				Partners LP			Guarantor			Non-Guarantor
																				(Parent)			Subsidiaries			Subsidiaries			Consolidated
Net income (loss)	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	50,549		$	(55,789	)	OPERATING ACTIVITIES:
																			Net cash provided by (used in) operating activities	$	(12,428	)	$	140,794		$	4,268		$	132,634
Other comprehensive income (loss)	—			—			189			(26		)	—			163
																			INVESTING ACTIVITIES:
Comprehensive income (loss)	$	(59,199	)	$	(21,280	)	$	(29,417	)	$	3,721		$	50,549		$	(55,626	)	Purchases of long-lived assets	—			(59,903		)	(12,572		)	(72,475		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(452,087		)	(38,718		)	—			(490,805		)
																			Cash flows from commodity derivatives	—			11,579			—			11,579
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Proceeds from sales of assets	—			5,080			—			5,080
																			Net cash used in investing activities	(452,087		)	(81,962		)	(12,572		)	(546,621		)
	Six Months Ended September 30, 2013
	NGL Energy																		FINANCING ACTIVITIES:
	Partners LP			Guarantor			Non-Guarantor			Consolidating									Proceeds from borrowings under revolving credit facilities	—			1,227,975			—			1,227,975
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Payments on revolving credit facilities	—			(964,475		)	—			(964,475		)
																			Issuance of notes	250,000			—			—			250,000
Net income (loss)	$	(18,574	)	$	(10,206	)	$	1,806		$	8,534		$	(18,440	)				Proceeds from borrowings on other long-term debt	—			634			19			653
																			Payments on other long-term debt	—			(4,837		)	—			(4,837		)
Other comprehensive loss	—			—			(30		)	—			(30		)				Debt issuance costs	(777		)	(19,412		)	—			(20,189		)
																			Contributions	510			—			403			913
Comprehensive income (loss)	$	(18,574	)	$	(10,206	)	$	1,776		$	8,534		$	(18,470	)				Distributions	(71,608		)	—			(74		)	(71,682		)
																			Proceeds from sale of common units, net of offering costs	(642		)	—			—			(642		)
NGL ENERGY PARTNERS LP																			Net changes in advances with consolidated entities	286,991			(295,105		)	8,114			—
Condensed Consolidating Statement of Cash Flows																			Net cash provided by (used in) financing activities	464,474			(55,220		)	8,462			417,716
(U.S. Dollars in Thousands)																			Net increase (decrease) in cash and cash equivalents	(41		)	3,612			158			3,729
																			Cash and cash equivalents, beginning of period	41			7,594			197			7,832
	Six Months Ended September 30, 2014																		Cash and cash equivalents, end of period	$	—		$	11,206		$	355		$	11,561
	NGL Energy
	Partners LP			NGL Energy			Guarantor			Non-Guarantor									NGL ENERGY PARTNERS LP
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated						Condensed Consolidating Statement of Cash Flows
OPERATING ACTIVITIES:																			(U.S. Dollars in Thousands)
Net cash provided by (used in) operating activities	$	(8,180	)	$	(15,383	)	$	(56,019	)	$	17,947		$	(61,635	)
																				Year Ended March 31, 2012
INVESTING ACTIVITIES:																				NGL Energy
Purchases of long-lived assets	—			—			(81,710		)	(1,141		)	(82,851		)					Partners LP			Guarantor			Non-Guarantor
Acquisitions of businesses, including acquired working capital, net of cash acquired	—			—			(657,514		)	(1,250		)	(658,764		)					(Parent)			Subsidiaries			Subsidiaries			Consolidated
Cash flows from commodity derivatives	—			—			4,327			—			4,327						OPERATING ACTIVITIES:
Proceeds from sales of assets	—			—			8,741			—			8,741						Net cash provided by (used in) operating activities	$	—		$	90,477		$	(148	)	$	90,329
Investments in unconsolidated entities	—			—			(6,106		)	(20,284		)	(26,390		)
Distributions of capital from unconsolidated entities	—			—			2,774			1,875			4,649						INVESTING ACTIVITIES:
Net cash used in investing activities	—			—			(729,488		)	(20,800		)	(750,288		)				Purchases of long-lived assets	—			(6,667		)	(877		)	(7,544		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(291,097		)	(6,304		)	—			(297,401		)
FINANCING ACTIVITIES:																			Cash flows from commodity derivatives	—			6,464			—			6,464
Proceeds from borrowings under revolving credit facilities	—			—			1,923,500			56,000			1,979,500						Proceeds from sales of assets	—			1,238			—			1,238
Payments on revolving credit facilities	—			—			(1,766,000		)	(38,000		)	(1,804,000		)				Other	—			346			—			346
Issuance of notes	—			400,000			—			—			400,000						Net cash used in investing activities	(291,097		)	(4,923		)	(877		)	(296,897		)
Payments on other long-term debt	—			—			(4,173		)	(2		)	(4,175		)
Debt issuance costs	(269		)	(7,209		)	(1,720		)	—			(9,198		)				FINANCING ACTIVITIES:
Contributions	395			—			—			—			395						Proceeds from borrowings under revolving credit facilities	—			478,900			—			478,900
Distributions to owners	(111,008		)	—			—			—			(111,008		)				Payments on revolving credit facilities	—			(329,900		)	—			(329,900		)
Distributions to noncontrolling interest partners	—			—			—			(8,654		)	(8,654		)				Payments on other long-term debt	—			(1,278		)	—			(1,278		)
Proceeds from sale of common units, net of offering costs	370,446			—			—			—			370,446						Debt issuance costs	—			(2,380		)	—			(2,380		)
Net changes in advances with consolidated entities	(249,724		)	(377,408		)	632,995			(5,863		)	—						Contributions	—			—			440			440
Net cash provided by financing activities	9,840			15,383			784,602			3,481			813,306						Distributions	(19,060		)	—			—			(19,060		)
Net increase (decrease) in cash and cash equivalents	1,660			—			(905		)	628			1,383						Proceeds from sale of common units, net of offering costs	74,759			—			—			74,759
Cash and cash equivalents, beginning of period	1,181			—			8,728			531			10,440						Repurchase of common units	(3,418		)	—			—			(3,418		)
Cash and cash equivalents, end of period	$	2,841		$	—		$	7,823		$	1,159		$	11,823					Net changes in advances with consolidated entities	238,816			(239,476		)	660			—
																			Net cash provided by (used in) financing activities	291,097			(94,134		)	1,100			198,063
																			Net increase (decrease) in cash and cash equivalents	—			(8,580		)	75			(8,505		)
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Cash and cash equivalents, beginning of period	41			16,174			122			16,337
																			Cash and cash equivalents, end of period	$	41		$	7,594		$	197		$	7,832
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Cash Flows
(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2013
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor
	(Parent)			Subsidiaries			Subsidiaries			Consolidated
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	$	(8,312	)	$	(44,607	)	$	4,175		$	(48,744	)
INVESTING ACTIVITIES:
Purchases of long-lived assets	—			(37,180		)	(30,219		)	(67,399		)
Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,085		)	(56,237		)	(2,283		)	(392,605		)
Cash flows from commodity derivatives	—			(19,074		)	—			(19,074		)
Proceeds from sales of assets	—			2,223			1			2,224
Net cash used in investing activities	(334,085		)	(110,268		)	(32,501		)	(476,854		)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facility	—			1,061,500			—			1,061,500
Payments on revolving credit facility	—			(893,000		)	—			(893,000		)
Proceeds from borrowings on other long-term debt	—			780			100			880
Payments on other long-term debt	—			(4,499		)	(8		)	(4,507		)
Debt issuance costs	(133		)	(2,085		)	—			(2,218		)
Contributions	504			—			1,940			2,444
Distributions to owners	(60,258		)	—			(365		)	(60,623		)
Proceeds from sale of common units, net of offering costs	415,089			—			—			415,089
Net changes in advances with consolidated entities	(11,459		)	(15,123		)	26,582			—
Net cash provided by financing activities	343,743			147,573			28,249			519,565
Net increase (decrease) in cash and cash equivalents	1,346			(7,302		)	(77		)	(6,033		)
Cash and cash equivalents, beginning of period	—			11,206			355			11,561
Cash and cash equivalents, end of period	$	1,346		$	3,904		$	278		$	5,528

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Significant Accounting Policies
Basis of Presentation	Basis of Presentation					Basis of Presentation
	The unaudited condensed consolidated financial statements as of and for the three months and six months ended September 30, 2014 and 2013 include our accounts and those of our controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All significant intercompany transactions and account balances have been eliminated in consolidation. The unaudited condensed consolidated balance sheet at March 31, 2014 is derived from audited financial statements. We have made certain reclassifications to prior period financial statements to conform to classification methods used in fiscal year 2015. These reclassifications had no impact on previously reported amounts of equity or net income.					Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of the Partnership and its controlled subsidiaries. All significant intercompany transactions and account balances have been eliminated in consolidation.
	The accompanying unaudited condensed consolidated financial statements have been 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. 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 of only normal recurring items, unless otherwise disclosed herein. Accordingly, the unaudited condensed consolidated financial statements do not include all the 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 not misleading. These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the fiscal year ended March 31, 2014 included in our Annual Report on Form 10-K (the “Annual Report”). Due to the seasonal nature of our natural gas liquids operations and other factors, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.					We have made certain reclassifications to the prior period financial statements to conform with classification methods used in fiscal 2014. These reclassifications had no impact on previously-reported amounts of equity or net income. In addition, certain balances at March 31, 2013 were adjusted to reflect the final acquisition accounting for certain business combinations.
Use of Estimates	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 reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period. Actual results could differ from those estimates.					The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period.
						Critical estimates we make in the preparation of our consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations; the collectability of accounts receivable; the recoverability of inventories; useful lives and recoverability of property, plant and equipment and amortizable intangible assets; the impairment of goodwill; the fair value of derivative financial investments; 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 Measurements
	We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.					We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.
	We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:					We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	·         Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.					·                  Level 1 — Quoted prices (unadjusted) 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 quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at September 30, 2014 and March 31, 2014 (see Note 11). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.					·                  Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at March 31, 2014 and 2013 (see Note 12). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model 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. We did not have any fair value measurements categorized as Level 3 at September 30, 2014 or March 31, 2014.					·                  Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at March 31, 2014 or 2013.
	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 the fair value measurement requires judgment, considering factors specific to 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 the fair value measurement requires judgment, considering factors specific to the asset or liability.
Derivative Financial Instruments						Derivative Financial Instruments
						We record our derivative financial instrument contracts at fair value in the consolidated balance sheets, with changes in the fair value of our commodity derivative instruments included in our consolidated statements of operations in cost of sales. Contracts that qualify for the normal purchase or sale exemption and are designated as such are not accounted for as derivatives at market value and, accordingly, are recorded when the delivery occurs.
						We have not designated any financial instruments as hedges for accounting purposes. All mark-to-market gains and losses on commodity derivative instruments that do not qualify as normal purchases or sales, whether cash transactions or non-cash mark-to-market adjustments, are reported within cost of sales in the consolidated statements of operations, regardless of whether the contract is physically or financially settled.
						We utilize various commodity derivative financial instrument contracts to help reduce our exposure to variability in future commodity prices. We do not enter 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 the 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 market risk and credit risk. Market risk is the risk that the value of the portfolio will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from non-performance by suppliers, customers, or financial counterparties to a contract. We take an active role in managing and controlling market and credit risk and have established control procedures that we review on an ongoing basis. We monitor market risk through a variety of techniques and attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures.
Revenue Recognition	Revenue Recognition					Revenue Recognition
	We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, transportation, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Pursuant to terminaling services agreements with certain of our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Such measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.					We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for the wastewater disposal business are recognized upon receipt of the wastewater at our disposal facilities.
	We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our condensed consolidated statements of operations.					We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in the 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 concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.					We enter into certain contracts whereby we agree to purchase product from a counterparty and to sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.
Cost of Sales						Cost of Sales
						We include in cost of sales all costs we incur to acquire products, including the costs of purchasing, terminaling, and transporting inventory prior to delivery to our customers. Cost of sales does not include any depreciation of our property, plant and equipment. Cost of sales does include amortization of certain contract-based intangible assets of $6.2 million, $5.3 million, and $0.8 million during the years ended March 31, 2014, 2013, and 2012, respectively.
Depreciation and Amortization						Depreciation and Amortization
						Depreciation and amortization in the consolidated statements of operations includes all depreciation of our property, plant and equipment and amortization of intangible assets other than debt issuance costs, for which the amortization is recorded to interest expense, and certain contract-based intangible assets, for which the amortization is recorded to cost of sales.
Cash and Cash Equivalents						Cash and Cash Equivalents
						Cash and cash equivalents include cash on hand, demand and time deposits, and funds invested in highly liquid instruments with maturities of three months or less at the date of purchase. At times, certain account balances may exceed federally insured limits.
						Supplemental cash flow information is as follows:
							Year Ended March 31,
							2014			2013			2012
							(in thousands)
						Interest paid, exclusive of debt issuance costs and letter of credit fees	$	31,827		$	27,384		$	4,966
						Income taxes paid	$	1,639		$	1,027		$	430
						Cash flows from commodity derivative instruments are classified as cash flows from investing activities in the consolidated statements of cash flows.
Accounts Receivable and Concentration of Credit Risk						Accounts Receivable and Concentration of Credit Risk
						We operate in the United States and Canada. We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions. The allowance for doubtful accounts is based on our assessment of the collectability of customer accounts, which assessment considers the overall creditworthiness of customers and any specific disputes. Accounts receivable are considered past due or delinquent based on contractual terms. We write off accounts receivable against the allowance for doubtful accounts when collection efforts have been exhausted.
						We execute netting agreements with certain customers to mitigate our credit risk. Receivables and payables are reflected at a net balance to the extent a netting agreement is in place and we intend to settle on a net basis.
						Our accounts receivable consist of the following:
							March 31, 2014						March 31, 2013
													Gross
							Gross			Allowance for			Receivable			Allowance for
						Segment	Receivable			Doubtful Accounts			(Note 2)			Doubtful Accounts
							(in thousands)
						Crude oil logistics	$	411,090		$	105		$	360,589		$	11
						Water solutions	25,700			405			9,618			29
						Liquids	192,529			617			144,267			76
						Retail propane	75,606			1,667			49,233			1,644
						Refined products	105,670			—			—			—
						Renewables	54,466			—			—			—
						Other	38,665			28			810			—
							$	903,726		$	2,822		$	564,517		$	1,760
						Changes in the allowance for doubtful accounts are as follows:
							Year Ended March 31,
							2014			2013			2012
							(in thousands)
						Allowance for doubtful accounts, beginning of period	$	1,760		$	818		$	161
						Provision for doubtful accounts	2,172			1,315			1,049
						Write off of uncollectible accounts	(1,110		)	(373		)	(392		)
						Allowance for doubtful accounts, end of period	$	2,822		$	1,760		$	818
						For the year ended March 31, 2014, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. For the year ended March 31, 2013, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. At March 31, 2013, one customer of our crude oil logistics segment represented 10% of our consolidated accounts receivable balance.
Inventories	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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.					We value our inventory 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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
						Inventories consist of the following:
							March 31,
							2014			2013
							(in thousands)
						Crude oil	$	156,473		$	46,156
						Natural gas liquids —
						Propane	85,159			45,428
						Butane and other	19,051			24,090
						Refined products	23,209			—
						Renewables	11,778			—
						Other	14,490			11,221
							$	310,160		$	126,895
Investments in Unconsolidated Entities	Investments in Unconsolidated Entities					Investments in Unconsolidated Entities
	In December 2013, as part of our acquisition of Gavilon, LLC (“Gavilon Energy”), we acquired a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”) and an 11% interest in a limited liability company that owns an ethanol production facility. In June 2014, we acquired an interest in a limited liability company that operates a water supply business. On July 1, 2014, as part of our acquisition of TransMontaigne Inc. (“TransMontaigne”), we acquired TLP, which owns a 42.5% interest in BOSTCO and a 50% interest in Frontera. We account for these investments 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 book value of the net assets of the investment entity.					As part of the December 2013 acquisition of Gavilon Energy, we acquired a 50% interest in Glass Mountain and an 11% interest in a limited liability company that owns an ethanol production facility. We account for these investments under the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheet; instead, our ownership interests are reported within “Investments in Unconsolidated Entities” on our consolidated balance sheet. We record our share of any income or loss generated by these entities as an increase to our equity method investments, and record any distributions we receive from these entities as reductions to our equity method investments.
	Our investments in unconsolidated entities consist of the following:
		September 30,		March 31,
		2014		2014
		(in thousands)
	Glass Mountain (1)	$	189,847	$	181,488
	Ethanol production facility	9,361		8,333
	Water supply company	15,026		—
	BOSTCO (2)	244,092		—
	Frontera	24,318		—
	Total	$	482,644	$	189,821
	(1)     When we acquired Gavilon we recorded the investment in Glass Mountain at fair value. The fair value of our investment in Glass Mountain exceeds our share of the historical net book value of Glass Mountain’s net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.
	(2)     When we acquired TransMontaigne, we recorded the investment in BOSTCO at fair value. The fair value of our investment in BOSTCO exceeds our share of the historical net book value of BOSTCO’s net assets by approximately $24 million.
Accrued Expenses and Other Payables						Accrued Expenses and Other Payables
						Accrued expenses and other payables consist of the following:
							March 31,
										2013
							2014			(Note 4)
							(in thousands)
						Accrued compensation and benefits	$	45,006		$	27,252
						Derivative liabilities	42,214			12,701
						Income and other tax liabilities	13,421			22,659
						Product exchange liabilities	3,719			6,741
						Other	37,330			16,253
							$	141,690		$	85,606
Property, Plant and Equipment						Property, Plant and Equipment
						We record property, plant and equipment at cost, less accumulated depreciation. Acquisitions and improvements are capitalized, and maintenance and repairs are expensed as incurred. As we dispose of assets, we remove the cost and related accumulated depreciation from the accounts, and any resulting gain or loss is included in other income. We compute depreciation expense using the straight-line method over the estimated useful lives of the assets (see Note 5).
						We evaluate the carrying value of our property, plant and equipment for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group.
Intangible Assets						Intangible Assets
						Our intangible assets include contracts and arrangements acquired in business combinations, including lease agreements, customer relationships, covenants not to compete, and trade names. In addition, we capitalize certain debt issuance costs incurred in our long-term debt arrangements. We amortize our intangible assets on a straight-line basis over the assets’ estimated useful lives (see Note 7). We amortize debt issuance costs over the terms of the related debt on a method that approximates the effective interest method.
						We evaluate the carrying value of our amortizable intangible assets for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group. When we cease to use an acquired trade name, we test the trade name for impairment using the “relief from royalty” method and we begin amortizing the trade name over its estimated useful life as a defensive asset.
Goodwill						Goodwill
						Goodwill represents the excess of cost over the fair value of net assets of acquired businesses. Business combinations are accounted for using the “acquisition method” (see Note 4). We expect that substantially all of our goodwill at March 31, 2014 is deductible for income tax purposes.
						Goodwill and intangible assets determined to have an indefinite useful life are not amortized, but instead are evaluated for impairment periodically. We evaluate goodwill and indefinite-lived intangible assets for impairment annually, or more often if events or circumstances indicate that the assets might be impaired. We perform the annual evaluation at January 1 of each year.
						To perform this assessment, we consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. If we conclude that it is more likely than not that the fair value of a reporting unit exceeds its carrying amount, we perform the following two-step goodwill impairment test:
						·                  In the first step of the goodwill impairment test, we compare the fair value of the reporting unit with its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its fair value, we perform the second step of the goodwill impairment test to measure the amount of impairment loss, if any.
						·                  In the second step of the goodwill impairment test, we compare the implied fair value of reporting unit goodwill with the carrying amount of that goodwill. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to that excess.
						Estimates and assumptions used to perform the impairment evaluation are inherently uncertain and can significantly affect the outcome of the analysis. The estimates and assumptions we used in the annual assessment for impairment of goodwill included market participant considerations and future forecasted operating results. Changes in operating results and other assumptions could materially affect these estimates. Based on our assessment of qualitative factors, we determined that the two-step impairment test was not required. Accordingly, we did not record any goodwill impairments during the years ended March 31, 2014, 2013, and 2012.
Product Exchanges						Product Exchanges
						Quantities of products receivable or returnable under exchange agreements are reported within prepaid expenses and other current assets or within accrued expenses and other payables on the consolidated balance sheets. We estimate the value of product exchange assets and liabilities based on the weighted-average cost basis of the inventory we have delivered or will deliver on the exchange, plus or minus location differentials.
Advance Payments Received from Customers						Advance Payments Received from Customers
						We record customer advances on product purchases as a liability on the consolidated balance sheets.
Noncontrolling Interests	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’ share of these entities.					We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our consolidated statements of operations represents the other owners’ share of the net income (loss) of these entities.
	On July 1, 2014, as part of our acquisition of TransMontaigne, we acquired a 19.7% limited partner interest in TLP. We have attributed net earnings allocable to TLP’s limited partners to the controlling and noncontrolling interests based on the relative ownership interests in TLP as well as including certain adjustments related to our acquisition accounting. Net earnings allocable to TLP’s limited partners are net of the earnings allocable to TLP’s general partner interest. The earnings allocable to TLP’s general partner interest include the distributions of available cash (as defined by TLP’s partnership agreement) attributable to the period to TLP’s general partner interest and incentive distribution rights, net of adjustments for TLP’s general partner’s share of undistributed earnings. Undistributed earnings are allocated to TLP’s limited partners and TLP’s general partner interest based on their respective sharing of earnings or losses specified in TLP’s partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively.
Water Facility Development Agreement						Water Facility Development Agreement
						In connection with one of our business combinations, we entered into a development agreement whereby we may acquire additional water disposal facilities in Texas. Under this agreement, the other party (the “Developer”) may develop facilities in a designated area. We then have the option to operate the facility for a period of up to 90 days, during which time we may elect to purchase the facility. If we elect to purchase the facility, the Developer may choose one of two options specified in the agreement for the calculation of the purchase price.
						During the period between which we have begun operating the facility and we have decided whether to purchase the facility, we are entitled to a fee for operating the facility, which is forfeitable if we elect not to purchase the facility. We recognize revenue for these operator fees once they cease to be forfeitable. When we elect to purchase a facility, we account for the transaction as a business combination.
Business Combination Measurement Period	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 fair value of the assets acquired and liabilities assumed in a business combination. As described 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 described in Note 4, we made certain adjustments during the six months ended September 30, 2014 to our estimates of the acquisition-date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2014.					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 to obtain the information necessary to identify and measure the value of the assets acquired and liabilities assumed in a business combination. As described in Note 4, certain of our acquisitions during the year ended March 31, 2014 are still within this measurement period, and as a result, the acquisition-date fair values we have recorded for the acquired assets and assumed liabilities are subject to change.
						Also as described in Note 4, we made certain adjustments during the year ended March 31, 2014 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2013. We retrospectively adjusted the March 31, 2013 consolidated balance sheet for these adjustments. Due to the immateriality of these adjustments, we did not retrospectively adjust the consolidated statement of operations for the year ended March 31, 2013 for these measurement period adjustments.
Discontinued Operations						Discontinued Operations
						In April 2014, the Financial Accounting Standards Board issued an Accounting Standards Update that changes the criteria for reporting discontinued operations. Under the new standard, a disposal of part of an entity is not classified as a discontinued operation unless the disposal represents a strategic shift that will have a major effect on an entity’s operations and financial results. We adopted the new standard during the fiscal year ended March 31, 2014.
						As described in Note 14, during the year ended March 31, 2014, we sold our compressor leasing business and wound down our natural gas marketing business. These actions do not represent a strategic shift that had a major effect on our operations, and do not meet the criteria under the new accounting standard for these businesses to be reported as discontinued operations.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Significant Accounting Policies
Schedule of supplemental cash flow information
		Three Months Ended				Six Months Ended
		September 30,				September 30,					Year Ended March 31,
		2014		2013		2014		2013			2014			2013			2012
		(in thousands)									(in thousands)
	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	10,445	$	8,423	$	36,429	$	16,908	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	31,827		$	27,384		$	4,966
	Income taxes paid	$	1,241	$	369	$	2,246	$	650	Income taxes paid	$	1,639		$	1,027		$	430
	Value of common units issued in business combinations	$	—	$	80,619	$	—	$	80,619
Schedule of accounts receivable
											March 31, 2014						March 31, 2013
																	Gross
											Gross			Allowance for			Receivable			Allowance for
										Segment	Receivable			Doubtful Accounts			(Note 2)			Doubtful Accounts
											(in thousands)
										Crude oil logistics	$	411,090		$	105		$	360,589		$	11
										Water solutions	25,700			405			9,618			29
										Liquids	192,529			617			144,267			76
										Retail propane	75,606			1,667			49,233			1,644
										Refined products	105,670			—			—			—
										Renewables	54,466			—			—			—
										Other	38,665			28			810			—
											$	903,726		$	2,822		$	564,517		$	1,760
Schedule of changes in the allowance for doubtful accounts
											Year Ended March 31,
											2014			2013			2012
											(in thousands)
										Allowance for doubtful accounts, beginning of period	$	1,760		$	818		$	161
										Provision for doubtful accounts	2,172			1,315			1,049
										Write off of uncollectible accounts	(1,110		)	(373		)	(392		)
										Allowance for doubtful accounts, end of period	$	2,822		$	1,760		$	818
Schedule of inventories
											March 31,
		September 30,		March 31,							2014			2013
		2014		2014							(in thousands)
		(in thousands)								Crude oil	$	156,473		$	46,156
	Crude oil	$	136,722	$	156,473					Natural gas liquids —
	Natural gas liquids —									Propane	85,159			45,428
	Propane	207,694		85,159						Butane and other	19,051			24,090
	Butane	84,822		15,106						Refined products	23,209			—
	Other	27,091		3,945						Renewables	11,778			—
	Refined products —									Other	14,490			11,221
	Gasoline	219,111		15,597							$	310,160		$	126,895
	Diesel	214,567		7,298
	Other	3,675		314
	Renewables	36,517		11,778
	Other	11,390		14,490
	Total	$	941,589	$	310,160
Schedule of accrued expenses and other payables
		September 30,		March 31,							March 31,
		2014		2014										2013
		(in thousands)									2014			(Note 4)
	Accrued compensation and benefits	$	49,146	$	45,006						(in thousands)
	Derivative liabilities	39,023		42,214						Accrued compensation and benefits	$	45,006		$	27,252
	Product exchange liabilities	43,185		3,719						Derivative liabilities	42,214			12,701
	Accrued interest	23,945		18,668						Income and other tax liabilities	13,421			22,659
	Income and other tax liabilities	38,255		13,421						Product exchange liabilities	3,719			6,741
	Other	24,928		18,662						Other	37,330			16,253
	Total	$	218,482	$	141,690						$	141,690		$	85,606

Earnings_per_Unit_Tables

Earnings per Unit (Tables)	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Earnings Per Unit
Schedule of earnings per common and subordinated unit
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands, except unit and per unit amounts)
		(in thousands, except unit and per unit amounts)
	Net loss attributable to parent equity	$	(19,224	)	$	(941	)	$	(59,199	)	$	(18,574	)	Income attributable to parent equity	$	47,655		$	47,940		$	7,876
	Less: net income allocated to general partner (1)	(11,056		)	(2,451		)	(20,437		)	(4,139		)	Income allocated to general partner (1)	(14,148		)	(2,917		)	(8		)
	Net loss allocated to subordinated unitholders (2)	—			562			4,013			3,076			Income attributable to limited partners	$	33,507		$	45,023		$	7,868
	Net loss allocated to common unitholders	$	(30,280	)	$	(2,830	)	$	(75,623	)	$	(19,637	)
														Income allocated to:
	Weighted average common units outstanding	88,331,653			58,909,389			81,267,742			53,336,969			Common unitholders	$	31,614		$	39,517		$	4,859
														Subordinated unitholders	$	1,893		$	5,506		$	3,009
	Loss per common unit - basic and diluted	$	(0.34	)	$	(0.05	)	$	(0.93	)	$	(0.37	)
														Weighted average common units outstanding	61,970,471			41,353,574			15,169,983
														Weighted average subordinated units outstanding	5,919,346			5,919,346			5,175,384
	(1)     The net income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are described in Note 10.
	(2)     All outstanding subordinated units converted to common units in August 2014. Since the subordinated units did not share in the distribution of cash generated during the three months ended September 30, 2014, we did not allocate any earnings or loss during this period to the subordinated unitholders. During the three months ended June 30, 2014 and the six months ended September 30, 2013, 5,919,346 subordinated units were outstanding. The loss per subordinated unit was $(0.68) for the three months ended June 30, 2014, $(0.09) for the three months ended September 30, 2013, and $(0.52) for the six months ended September 30, 2013.													Income per common unit - basic and diluted	$	0.51		$	0.96		$	0.32
														Income per subordinated unit - basic and diluted	$	0.32		$	0.93		$	0.58
														(1)         The income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights (“IDRs”), which are described in Note 11.

Acquisitions_Tables

Acquisitions (Tables)	6 Months Ended										12 Months Ended
	Sep. 30, 2014										Mar. 31, 2014
Acquisitions
Schedule of future amortization of liability	The future amortization of this liability is shown below (in thousands):										The future amortization of this liability is shown below (in thousands):
	Year Ending March 31,										Year Ending March 31,
	2015 (six months)	$	3,670								2015	$	6,500
	2016	4,040									2016	3,260
	2017	360									2017	300
Schedule of pro forma earnings per unit based on the common and subordinated units outstanding
												Year Ended March 31,
												2014			2013
												(in thousands, except per unit amounts)
											Revenues	$	9,800,398		$	5,697,988
											Net income (loss)	798			(72,171		)
											Net loss attributable to limited partners	(14,446		)	(75,251		)
											Basic and diluted loss per common unit	(0.18		)	(0.95		)
											Basic and diluted loss per subordinated unit	(0.18		)	(0.95		)
Gavilon Energy
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated at						Accounts receivable - trade	$	349,529
					at						Accounts receivable - affiliates	2,564
					March 31,						Inventories	107,430
		Final			2014			Change			Prepaid expenses and other current assets	68,322
		(in thousands)									Property, plant and equipment:
	Accounts receivable - trade	$	326,484		$	349,529		$	(23,045	)	Crude oil tanks and related equipment (3—40 years)	77,429
	Accounts receivable - affiliates	2,564			2,564			—			Vehicles (3 years)	791
	Inventories	107,430			107,430			—			Information technology equipment (3—7 years)	4,046
	Prepaid expenses and other current assets	68,322			68,322			—			Buildings and leasehold improvements (3—40 years)	7,716
	Property, plant and equipment:										Land	6,427
	Vehicles (3 years)	327			791			(464		)	Linefill and tank bottoms	15,230
	Crude oil tanks and related equipment (3–40 years)	83,797			77,429			6,368			Other (7 years)	170
	Information technology equipment (3–7 years)	4,049			4,046			3			Construction in process	7,190
	Buildings and leasehold improvements (3–40 years)	7,817			7,716			101			Goodwill	359,169
	Land	6,427			6,427			—			Intangible assets:
	Tank bottoms	16,930			15,230			1,700			Customer relationships (10—20 years)	101,600
	Other (7 years)	162			170			(8		)	Lease agreements (1—5 years)	8,700
	Construction in progress	7,180			7,190			(10		)	Investments in unconsolidated entities	178,000
	Goodwill (1)	342,769			359,169			(16,400		)	Other noncurrent assets	9,918
	Intangible assets:										Accounts payable - trade	(342,792		)
	Customer relationships (10–20 years)	107,950			101,600			6,350			Accounts payable - affiliates	(2,585		)
	Lease agreements (1–5 years)	8,700			8,700			—			Accrued expenses and other payables	(70,999		)
	Pipeline capacity rights (30 years)	7,800			—			7,800			Advance payments received from customers	(10,667		)
	Investments in unconsolidated entities	183,000			178,000			5,000			Other noncurrent liabilities	(44,740		)
	Other noncurrent assets	2,287			9,918			(7,631		)	Fair value of net assets acquired	$	832,448
	Accounts payable - trade	(342,792		)	(342,792		)	—
	Accounts payable - affiliates	(2,585		)	(2,585		)	—
	Accrued expenses and other payables	(49,447		)	(70,999		)	21,552
	Advance payments received from customers	(10,667		)	(10,667		)	—
	Other noncurrent liabilities	(46,056		)	(44,740		)	(1,316		)
	Fair value of net assets acquired	$	832,448		$	832,448		$	—
	(1)     Primarily included in the crude oil logistics segment.
Oilfield Water Lines LP
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated						Accounts receivable - trade	$	7,268
					at						Inventories	154
					March 31,						Prepaid expenses and other current assets	402
		Final			2014			Change			Property, plant and equipment:
		(in thousands)									Land	710
	Accounts receivable - trade	$	6,837		$	7,268		$	(431	)	Water treatment facilities and equipment (3—30 years)	23,173
	Inventories	154			154			—			Vehicles (5—10 years)	8,157
	Prepaid expenses and other current assets	402			402			—			Buildings and leasehold improvements (7—30 years)	2,198
	Property, plant and equipment:										Other (3—5 years)	53
	Vehicles (5–10 years)	8,143			8,157			(14		)	Intangible assets:
	Water treatment facilities and equipment (3–30 years)	23,173			23,173			—			Customer relationships (10 years)	110,000
	Buildings and leasehold improvements (7–30 years)	2,198			2,198			—			Non-compete agreements (2.5 years)	2,000
	Land	710			710			—			Goodwill	89,699
	Other (3–5 years)	53			53			—			Accounts payable - trade	(6,469		)
	Intangible assets:										Accrued expenses and other payables	(992		)
	Customer relationships (8–10 years)	110,000			110,000			—			Other noncurrent liabilities	(64		)
	Non-compete agreements (3 years)	2,000			2,000			—			Fair value of net assets acquired	$	236,289
	Goodwill	90,144			89,699			445
	Accounts payable - trade	(6,469		)	(6,469		)	—
	Accrued expenses and other payables	(992		)	(992		)	—
	Other noncurrent liabilities	(64		)	(64		)	—
	Fair value of net assets acquired	$	236,289		$	236,289		$	—
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	167,732
											Value of common units issued	68,557
											Total consideration paid	$	236,289
Other Water Solutions
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
											Accounts receivable - trade	$	2,391
											Inventories	390
											Prepaid expenses and other current assets	61
											Property, plant and equipment:
											Land	419
											Vehicles (5—10 years)	90
											Water treatment facilities and equipment (3—30 years)	24,933
											Buildings and leasehold improvements (7—30 years)	3,036
											Other (3—5 years)	13
											Intangible assets:
											Customer relationships (8—10 years)	72,000
											Trade names (indefinite life)	3,325
											Non-compete agreements (3 years)	260
											Water facility development agreement (5 years)	14,000
											Water facility option agreement	2,500
											Goodwill	63,031
											Accounts payable - trade	(382		)
											Accrued expenses and other payables	(300		)
											Other noncurrent liabilities	(114		)
											Fair value of net assets acquired	$	185,653
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	178,867
											Value of common units issued	6,786
											Total consideration paid	$	185,653
Crude Oil Logistics
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated						Accounts receivable - trade	$	1,235
					at						Inventories	1,021
					March 31,						Prepaid expenses and other current assets	54
		Final			2014			Change			Property, plant and equipment:
		(in thousands)									Vehicles (5—10 years)	2,977
	Accounts receivable - trade	$	1,221		$	1,235		$	(14	)	Buildings and leasehold improvements (5—30 years)	280
	Inventories	1,021			1,021			—			Crude oil tanks and related equipment (2—30 years)	3,462
	Prepaid expenses and other current assets	58			54			4			Barges and towboats (20 years)	20,065
	Property, plant and equipment:										Other (3—5 years)	53
	Vehicles (5–10 years)	2,980			2,977			3			Intangible assets:
	Buildings and leasehold improvements (5–30 years)	58			280			(222		)	Customer relationships (3 years)	6,300
	Crude oil tanks and related equipment (2–30 years)	3,822			3,462			360			Non-compete agreements (3 years)	35
	Barges and towboats (20 years)	20,065			20,065			—			Trade names (indefinite life)	530
	Other (3–5 years)	57			53			4			Goodwill	37,867
	Intangible assets:										Accounts payable - trade	(665		)
	Customer relationships (3 years)	13,300			6,300			7,000			Accrued expenses and other payables	(124		)
	Non-compete agreements (3 years)	35			35			—			Fair value of net assets acquired	$	73,090
	Trade names (indefinite life)	530			530			—
	Goodwill	30,730			37,867			(7,137		)
	Accounts payable - trade	(521		)	(665		)	144
	Accrued expenses and other payables	(266		)	(124		)	(142		)
	Fair value of net assets acquired	$	73,090		$	73,090		$	—
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	67,842
											Value of common units issued	5,248
											Total consideration paid	$	73,090
High Sierra
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The fair values of the assets acquired and liabilities assumed in our acquisition of High Sierra are summarized below (in thousands):
											Accounts receivable - trade	$	395,311
											Accounts receivable - affiliates	7,724
											Inventories	43,575
											Derivative assets	10,646
											Forward purchase and sale contracts	34,717
											Prepaid expenses and other current assets	11,131
											Property, plant and equipment:
											Land	5,723
											Vehicles (5—10 years)	22,507
											Water treatment facilities and equipment (3—30 years)	64,057
											Crude oil tanks and related equipment (2—15 years)	17,851
											Buildings and leasehold improvements (5—30 years)	19,145
											Information technology equipment (3 years)	5,541
											Other (2—30 years)	11,010
											Construction in progress	9,621
											Intangible assets:
											Customer relationships (5—17 years)	245,000
											Lease contracts (1—10 years)	12,400
											Trade names (indefinite)	13,000
											Goodwill	220,884
											Accounts payable - trade	(417,369			)
											Accounts payable - affiliates	(9,014			)
											Advance payments received from customers	(1,237			)
											Accrued expenses and other payables	(35,611			)
											Derivative liabilities	(5,726			)
											Forward purchase and sale contracts	(18,680			)
											Long-term debt	(2,537			)
											Other noncurrent liabilities	(3,224			)
											Noncontrolling interest in consolidated subsidiary	(2,400			)
											Consideration paid, net of cash acquired	$		654,045
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	239,251
											Value of common units issued, net of issurance costs	414,794
											Total consideration paid	$	654,045
Pecos
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed
															Estimated at
															March 31,
												Final			2013			Change
												(in thousands)
											Accounts receivable - trade	$	73,609		$	73,704		$	(95	)
											Inventories	1,903			1,903			—
											Prepaid expenses and other current assets	1,426			1,426			—
											Property, plant and equipment:
											Vehicles (5—10 years)	22,097			19,193			2,904
											Buildings and leasehold improvements (5—30 years)	1,339			1,248			91
											Crude oil tanks and related equipment (2—15 years)	1,099			913			186
											Land	223			224			(1		)
											Other (3—5 years)	36			177			(141		)
											Intangible assets:
											Customer relationships	—			8,000			(8,000		)
											Trade names (indefinite life)	900			1,000			(100		)
											Goodwill	91,747			86,661			5,086
											Accounts payable - trade	(50,795		)	(50,808		)	13
											Accrued expenses and other payables	(963		)	(1,020		)	57
											Long-term debt	(10,234		)	(10,234		)	—
											Fair value of net assets acquired	$	132,387		$	132,387		$	—
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	87,444
											Value of common units issued	44,943
											Total consideration paid	$	132,387
Third Coast
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed
															Estimated at
															March 31,
												Final			2013			Change
												(in thousands)
											Accounts receivable - trade	$	2,195		$	2,248		$	(53	)
											Inventories	140			140			—
											Property, plant and equipment:
											Barges and towboats (20 years)	17,711			12,883			4,828
											Other	—			30			(30		)
											Intangible assets:
											Customer relationships (3 years)	3,000			4,000			(1,000		)
											Trade names (indefinite life)	850			500			350
											Goodwill	18,847			22,551			(3,704		)
											Other noncurrent assets	2,733			2,733			—
											Accounts payable - trade	(2,429		)	(2,048		)	(381		)
											Accrued expenses and other payables	(164		)	(154		)	(10		)
											Fair value of net assets acquired	$	42,883		$	42,883		$	—
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	35,000
											Value of common units issued	7,883
											Total consideration paid	$	42,883
Other Crude Oil Logistics and Water Solutions
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed
															Estimated at
															March 31,
												Final			2013			Change
												(in thousands)
											Accounts receivable - trade	$	2,676		$	2,660		$	16
											Inventories	191			191			—
											Prepaid expenses and other current assets	737			738			(1		)
											Property, plant and equipment:
											Land	218			191			27
											Vehicles (5—10 years)	853			771			82
											Water treatment facilities and equipment (3—30 years)	13,665			13,322			343
											Buildings and leasehold improvements (5—30 years)	895			2,233			(1,338		)
											Crude oil tanks and related equipment (2—15 years)	4,510			1,781			2,729
											Other (3—5 years)	27			2			25
											Construction in progress	490			693			(203		)
											Intangible assets:
											Customer relationships (5—10 years)	13,125			6,800			6,325
											Non-compete agreements (3 years)	164			510			(346		)
											Trade names (indefinite life)	2,100			500			1,600
											Goodwill	34,451			43,822			(9,371		)
											Accounts payable - trade	(3,374		)	(3,374		)	—
											Accrued expenses and other payables	(1,914		)	(2,026		)	112
											Notes payable	(1,340		)	(1,340		)	—
											Other noncurrent liabilities	(156		)	(156		)	—
											Noncontrolling interest	(2,333		)	(2,333		)	—
											Fair value of net assets acquired	$	64,985		$	64,985		$	—
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid, net of cash acquired	$	52,552
											Value of common units issued	12,433
											Total consideration paid	$	64,985
Retail Propane Combinations
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The fair values of the assets acquired and liabilities assumed in these six combinations are as follows (in thousands):
											Accounts receivable - trade	$	8,715
											Inventory	5,155
											Other current assets	1,228
											Property, plant and equipment:
											Land	1,945
											Retail propane equipment (5—20 years)	28,763
											Vehicles (5 years)	11,344
											Buildings and leasehold improvements (30 years)	7,052
											Other	1,201
											Intangible assets:
											Customer relationships (10—15 years)	16,890
											Trade names (indefinite)	2,924
											Non-compete agreements (5 years)	1,387
											Goodwill	21,983
											Other non-current assets	784
											Long-term debt, including current portion	(6,594		)
											Other assumed liabilities	(12,511		)
											Fair value of net assets acquired	$	90,266
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash consideration paid	$	71,392
											Value of common units issued	18,874
											Total consideration	$	90,266
Osterman
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The following table presents the final allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
											Accounts receivable - trade	$	9,350
											Inventories	3,869
											Prepaid expenses and other current assets	215
											Property, plant and equipment:
											Land	2,349
											Retail propane equipment (15—20 years)	47,160
											Vehicles (5—20 years)	7,699
											Buildings and leasehold improvements (30 years)	3,829
											Other (3—5 years)	732
											Intangible assets:
											Customer relationships (20 years)	54,500
											Trade names (indefinite life)	8,500
											Non-compete agreements (7 years)	700
											Goodwill	52,267
											Assumed liabilities	(9,654		)
											Consideration paid, net of cash acquired	$	181,516
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash paid at closing, net of cash acquired	$	94,873
											Fair value of common units issued at closing	81,880
											Working capital payment (paid in November 2012)	4,763
											Consideration paid, net of cash acquired	$	181,516
SemStream
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The following table presents the fair values of the assets acquired and liabilities assumed in the SemStream combination (in thousands):
											Inventories	$	104,226
											Derivative assets	3,578
											Assets held for sale	3,000
											Prepaid expenses and other current assets	9,833
											Property, plant and equipment:
											Land	3,470
											Natural gas liquids terminal assets (20—30 years)	41,434
											Vehicles and railcars (5 years)	470
											Other (5 years)	3,326
											Investment in capital lease	3,112
											Intangible assets:
											Customer relationships (8—15 years)	31,950
											Lease contracts (1—4 years)	1,008
											Goodwill	74,924
											Assumed current liabilities	(4,591		)
											Consideration paid	$	275,740
Pacer
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The following table presents the allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
											Accounts receivable - trade	$	4,389
											Inventories	965
											Prepaid expenses and other current assets	43
											Property, plant and equipment:
											Land	1,967
											Retail propane equipment (15—20 years)	12,793
											Vehicles (5 years)	3,090
											Buildings and leasehold improvements (30 years)	409
											Other (3—5 years)	59
											Intangible assets:
											Customer relationships (15 years)	23,560
											Trade names (indefinite life)	2,410
											Non-compete agreements	1,520
											Goodwill	15,782
											Assumed liabilities	(4,399		)
											Consideration paid	$	62,588
Schedule of consideration paid											Consideration paid consists of the following (in thousands):
											Cash	$	32,213
											Common units	30,375
											Consideration paid	$	62,588
North American
Acquisitions
Schedule of the fair value (and useful lives) of the assets acquired and liabilities assumed											The following table presents the allocation of the acquisition costs to the assets acquired and liabilities assumed, based on their fair values (in thousands):
											Accounts receivable - trade	$	10,338
											Inventories	3,437
											Prepaid expenses and other current assets	282
											Property, plant and equipment:
											Land	2,251
											Retail propane equipment (15—20 years)	24,790
											Natural gas liquids terminal assets (15—20 years)	1,044
											Vehicles (5—15 years)	5,819
											Buildings and leasehold improvements (30 years)	2,386
											Other (3—5 years)	634
											Intangible assets:
											Customer relationships (10 years)	12,600
											Trade names (10 years)	2,700
											Non-compete agreements (3 years)	700
											Goodwill	13,978
											Assumed liabilities	(11,129		)
											Consideration paid	$	69,830

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	6 Months Ended						12 Months Ended
	Sep. 30, 2014						Mar. 31, 2014
Property, Plant and Equipment
Schedule of property, plant and equipment
		September 30,		March 31,				March 31,
	Description and Estimated Useful Lives	2014		2014							2013
		(in thousands)					Description and Estimated Useful Lives	2014			(Note 2)
	Natural gas liquids terminal assets (2–30 years)	$	127,258	$	75,141			(in thousands)
	Refined products and renewables terminal assets and equipment (20 years)	419,411		—			Natural gas liquids terminal assets (2—30 years)	$	75,141		$	63,637
	Retail propane equipment (2–30 years)	167,825		160,758			Retail propane equipment (2—30 years)	160,758			152,802
	Vehicles and railcars (3–25 years)	172,799		152,676			Vehicles (3—25 years)	152,676			88,173
	Water treatment facilities and equipment (3–30 years)	209,644		180,985			Water treatment facilities and equipment (3—30 years)	180,985			91,944
	Crude oil tanks and related equipment (2–40 years)	145,287		106,125			Crude oil tanks and related equipment (2—40 years)	106,125			22,577
	Barges and towboats (5–40 years)	56,094		52,217			Barges and towboats (5—40 years)	52,217			25,963
	Information technology equipment (3–7 years)	30,519		20,768			Information technology equipment (3—7 years)	20,768			12,169
	Buildings and leasehold improvements (3–40 years)	77,415		60,004			Buildings and leasehold improvements (3—40 years)	60,004			48,975
	Land	88,350		30,241			Land	30,241			21,815
	Tank bottoms	17,679		13,403			Linefill and tank bottoms	13,403			—
	Other (3–30 years)	16,770		6,341			Other (5—30 years)	6,341			16,104
	Construction in progress	57,319		80,251			Construction in progress	80,251			32,405
		1,586,370		938,910				938,910			576,564
	Less: Accumulated depreciation	-153,057		(109,564		)	Less: Accumulated depreciation	(109,564		)	(50,127		)
	Net property, plant and equipment	$	1,433,313	$	829,346		Net property, plant and equipment	$	829,346		$	526,437

Goodwill_Tables

Goodwill (Tables)	6 Months Ended						12 Months Ended
	Sep. 30, 2014						Mar. 31, 2014
Goodwill and Intangible Assets
Schedule of changes in the balance of goodwill	The changes in the balance of goodwill during the six months ended September 30, 2014 were as follows (in thousands):
	Beginning of period	$	1,107,006					Year Ended March 31,
	Revisions to acquisition accounting (Note 4)	(21,614		)				2014		2013		2012
	Acquisitions (Note 4)	86,895						(in thousands)
	Disposal	(1,797		)			Beginning of period, as retrospectively adjusted (Note 2)	$	555,220	$	167,245	$	8,568
	End of period	$	1,170,490				Acquisitions	551,786		387,975		158,677
							End of period, as retrospectively adjusted (Note 2)	$	1,107,006	$	555,220	$	167,245
Schedule of goodwill by reportable segment, including changes to goodwill
		September 30,			March 31,			March 31,
		2014			2014			2014		2013
		(in thousands)						(in thousands)
	Crude oil logistics	$	579,845		$	606,383	Crude oil logistics	$	606,383	$	246,345
	Water solutions	320,106			262,203		Water solutions	262,203		109,470
	Liquids	91,135			90,135		Liquids	90,135		87,136
	Retail propane	114,285			114,285		Retail propane	114,285		112,269
	Refined products and renewables	65,119			34,000		Refined products	22,000		—
	Total	$	1,170,490		$	1,107,006	Renewables	12,000		—
								$	1,107,006	$	555,220

Intangible_Assets_Tables

Intangible Assets (Tables)	6 Months Ended														12 Months Ended
	Sep. 30, 2014														Mar. 31, 2014
Intangible Assets
Schedule of intangible assets
				September 30, 2014						March 31, 2014								March 31, 2014						March 31, 2013
		Amortizable		Gross Carrying			Accumulated			Gross Carrying			Accumulated											Gross Carrying
		Lives		Amount			Amortization			Amount			Amortization			Amortizable		Gross Carrying			Accumulated			Amount		Accumulated
				(in thousands)												Lives		Amount			Amortization			(Note 2)		Amortization
	Amortizable —																				(in thousands)
	Customer relationships (1)	3–20 years		$	761,992		$	119,439		$	697,405		$	83,261	Amortizable -
	Pipeline capacity rights	30 years		94,800			942			—			—		Customer relationships (1)	3–20 years		$	697,405		$	83,261		$	405,160	$	30,959
	Water facility development agreement	5 years		14,000			3,500			14,000			2,100		Water facility development agreement	5 years		14,000			2,100			—		—
	Executory contracts and other agreements	5–10 years		23,920			16,367			23,920			13,190		Lease and other agreements	5–8 years		23,920			13,190			15,210		7,018
	Non-compete agreements	2–7 years		14,412			8,302			14,161			6,388		Non-compete agreements	2–7 years		14,161			6,388			11,509		2,871
	Trade names	2–10 years		14,539			5,197			15,489			3,081		Trade names	1–10 years		15,489			3,081			2,784		326
	Debt issuance costs	5–10 years		53,289			12,737			44,089			8,708		Debt issuance costs	5–10 years		44,089			8,708			19,494		2,981
	Total amortizable			976,952			166,484			809,064			116,728		Total amortizable			809,064			116,728			454,157		44,155
	Non-amortizable —														Non-amortizable -
	Trade names			27,620						22,620					Trade names			22,620						31,430
	Total			$	1,004,572		$	166,484		$	831,684		$	116,728	Total			$	831,684		$	116,728		$	485,587	$	44,155
	(1)     The weighted-average remaining amortization period for customer relationship intangible assets is approximately 9 years.														(1)         The weighted-average remaining amortization period for customer relationship intangible assets is approximately nine years.
Schedule of amortization expense
		Three Months Ended						Six Months Ended								Year Ended March 31,
		September 30,						September 30,							Recorded in	2014			2013			2012
	Recorded In	2014			2013			2014			2013					(in thousands)
		(in thousands)													Depreciation and amortization	$	60,855		$	29,657		$	4,538
	Depreciation and amortization	$	21,711		$	11,324		$	42,604		$	20,600			Cost of sales	6,172			5,285			800
	Cost of sales	1,984			949			4,121			1,574				Interest expense	5,727			3,375			1,277
	Interest expense	2,117			1,065			4,029			2,462				Loss on early extinguishment of debt	—			5,769			—
	Total	$	25,812		$	13,338		$	50,754		$	24,636				$	72,754		$	44,086		$	6,615
Schedule of expected amortization of intangible assets	Expected amortization of our intangible assets is as follows (in thousands):														Expected amortization of our intangible assets is as follows (in thousands):
	Year Ending March 31,														Year Ending March 31,
	2015 (six months)	$	50,570												2015	$	88,970
	2016	97,432													2016	83,449
	2017	90,795													2017	76,826
	2018	86,818													2018	72,857
	2019	79,587													2019	66,826
	Thereafter	405,266													Thereafter	303,408
	Total	$	810,468													$	692,336

LongTerm_Obligations_Tables

Long-Term Obligations (Tables)	6 Months Ended															12 Months Ended
	Sep. 30, 2014															Mar. 31, 2014
Long-Term Debt
Schedule of long-term debt
		September 30,		March 31,													March 31,
		2014		2014													2014		2013
		(in thousands)															(in thousands)
	Revolving credit facility —															Revolving credit facility —
	Expansion capital borrowings	$	137,000	$	532,500											Expansion capital loans	$	532,500	$	441,500
	Working capital borrowings	942,500		389,500												Working capital loans	389,500		36,000
	5.125% Notes due 2019	400,000		—												Senior notes	250,000		250,000
	6.875% Notes due 2021	450,000		450,000												Unsecured notes	450,000		—
	6.650% Notes due 2022	250,000		250,000												Other notes payable	14,914		21,562
	TLP credit facility	252,000		—													1,636,914		749,062
	Other long-term debt	10,913		14,914
		2,442,413		1,636,914												Less - current maturities	7,080		8,626
	Less - current maturities	5,062		7,080												Long-term debt	$	1,629,834	$	740,436
	Long-term debt	$	2,437,351	$	1,629,834
Schedule of outstanding borrowings and interest rates under Revolving Credit Facility	At September 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):															At March 31, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
		Amount		Rate													Amount		Rate
	Expansion Capital Facility —															Expansion capital facility —
	LIBOR borrowings	$	137,000	1.91	%											LIBOR borrowings	$	532,500	1.91	%
	Working Capital Facility —															Working capital facility —
	LIBOR borrowings	942,500		1.91	%											LIBOR borrowings	358,000		1.91	%
																Base rate borrowings	31,500		4	%
Schedule of maturities of long-term debt
		Revolving								TLP		Other					Revolving						Other
		Credit		2019		2021		2022		Credit		Long-Term					Credit		Senior		Unsecured		Notes
	Year Ending March 31,	Facility		Notes		Notes		Notes		Facility		Debt		Total		Year Ending March 31,	Facility		Notes		Notes		Payable		Total
		(in thousands)																			(in thousands)
	2015 (six months)	$	—	$	—	$	—	$	—	$	—	$	2,345	$	2,345	2015	$	—	$	—	$	—	$	7,081	$	7,081
	2016	—		—		—		—		252,000		3,128		255,128		2016	—		—		—		3,614		3,614
	2017	—		—		—		—		—		2,362		2,362		2017	—		—		—		2,356		2,356
	2018	—		—		—		25,000		—		1,459		26,459		2018	—		25,000		—		1,449		26,449
	2019	1,079,500		—		—		50,000		—		1,438		1,130,938		2019	922,000		50,000		—		238		972,238
	Thereafter	—		400,000		450,000		175,000		—		181		1,025,181		Thereafter	—		175,000		450,000		176		625,176
	Total	$	1,079,500	$	400,000	$	450,000	$	250,000	$	252,000	$	10,913	$	2,442,413		$	922,000	$	250,000	$	450,000	$	14,914	$	1,636,914

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Commitments and Contingencies
Schedule of future minimum lease payments under contractual commitments	Future minimum lease payments under these agreements at September 30, 2014 are as follows (in thousands):					Future minimum lease payments under contractual commitments at March 31, 2014 are as follows (in thousands):
	Year Ending March 31,					Year Ending March 31,
	2015 (six months)	$	71,007			2015	$	133,170
	2016	106,384				2016	93,454
	2017	88,666				2017	64,209
	2018	74,265				2018	49,802
	2019	49,907				2019	29,213
	Thereafter	117,125				Thereafter	58,182
	Total	$	507,354			Total	$	428,030
Schedule of commitments outstanding						At March 31, 2014, we had the following such commitments outstanding:
		Volume		Value			Volume		Value
		(in thousands)					(in thousands)
	Natural gas liquids fixed-price purchase commitments (gallons)	88,574		$	102,000	Natural gas liquids fixed-price purchase commitments (gallons)	31,111		$	39,117
	Natural gas liquids index-price purchase commitments (gallons)	528,459		601,719		Natural gas liquids floating-price purchase commitments (gallons)	522,947		618,293
	Natural gas liquids fixed-price sale commitments (gallons)	278,391		351,137		Natural gas liquids fixed-price sale commitments (gallons)	63,944		77,682
	Natural gas liquids index-price sale commitments (gallons)	370,639		512,900		Natural gas liquids floating-price sale commitments (gallons)	272,495		395,095
	Crude oil index-price purchase commitments (barrels)	4,437		383,153		Crude oil fixed-price purchase commitments (barrels)	4,016		364,557
	Crude oil fixed-price sale commitments (barrels)	32		2,867		Crude oil fixed-price sale commitments (barrels)	3,574		324,765
	Crude oil index-price sale commitments (barrels)	3,920		337,528

Equity_Tables

Equity (Tables)	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Equity
Summary of common units issued as partial consideration for several acquisitions
													Osterman combination	4,000,000
													SemStream combination	8,932,031
													Pacer combination	1,500,000
													Total - Year Ended March 31, 2012	14,432,031
													High Sierra combination	20,703,510
													Retail propane combinations	850,676
													Crude oil logistics and water solutions combinations	516,978
													Pecos combination	1,834,414
													Third Coast combination	344,680
													Total - Year Ended March 31, 2013	24,250,258
													Water solutions combinations	222,381
													Crude oil logistics combinations	175,211
													OWL combination	2,463,287
													Total - Year Ended March 31, 2014	2,860,879
Schedule of equivalent units not eligible to receive distributions
														Equivalent
														Units Not
													Record Date	Eligible
													August 3, 2011	—
													October 31, 2011	4,000,000
													February 3, 2012	7,117,031
													April 30, 2012	3,932,031
													August 3, 2012	17,862,470
													October 29, 2012	516,978
													February 4, 2013	1,202,085
													May 6, 2013	—
													August 5, 2013	—
													November 4, 2013	979,886
													February 4, 2014	—
													May 5, 2014	—
Schedule of restricted unit activity
	Unvested restricted units at March 31, 2014	1,311,100											Unvested restricted units at March 31, 2012	—
	Units granted	333,903											Units granted	1,684,400
	Units vested and issued	(438,009	)										Units vested and issued	(156,802	)
	Units withheld for employee taxes	(231,194	)										Units withheld for employee taxes	(61,698	)
	Units forfeited	(117,000	)										Units forfeited	(21,000	)
	Unvested restricted units at September 30, 2014	858,800											Unvested restricted units at March 31, 2013	1,444,900
													Units granted	494,000
													Units vested and issued	(296,269	)
													Units withheld for employee taxes	(122,531	)
													Units forfeited	(209,000	)
													Unvested restricted units at March 31, 2014	1,311,100
Summary of scheduled vesting of the awards
	Vesting Date	Number of Awards											Vesting Date	Number of Awards
	July 1, 2015	334,800											July 1, 2014	408,300
	July 1, 2016	314,000											January 1, 2015	4,000
	July 1, 2017	178,500											July 1, 2015	341,300
	July 1, 2018	31,500											January 1, 2016	4,000
	Unvested restricted units at September 30, 2014	858,800											July 1, 2016	322,500
													January 1, 2017	4,000
													July 1, 2017	192,500
													January 1, 2018	4,000
													July 1, 2018	30,500
													Total unvested units at March 31, 2014	1,311,100
Schedule of estimated share-based expense to be recorded on the awards granted
													Year Ending March 31,
													2015	$	14,393
													2016	11,279
													2017	7,429
													2018	2,310
													2019	229
													Total	$	35,640
Schedule of rollforward of the liability related to equity-based compensation	Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our condensed consolidated balance sheets (in thousands):												Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our consolidated balance sheets (in thousands):
	Balance at March 31, 2014	$	10,012										Balance at March 31, 2012	$	—
	Expense recorded	21,659											Expense recorded	10,138
	Value of units vested and issued	(18,763		)									Value of units vested and issued	(3,627		)
	Taxes paid on behalf of participants	(9,901		)									Taxes paid on behalf of participants	(1,468		)
	Balance at September 30, 2014	$	3,007										Balance at March 31, 2013	5,043
													Expense recorded	17,804
													Value of units vested and issued	(9,085		)
													Taxes paid on behalf of participants	(3,750		)
													Balance at March 31, 2014	$	10,012
Partnership Equity
Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner
																	Amount			Amount Paid to			Amount Paid to
													Date Declared	Record Date		Date Paid	Per Unit			Limited Partners			General Partner
																				(in thousands)			(in thousands)
													July 25, 2011	August 3, 2011		August 12, 2011	$	0.1669		$	2,467		$	3
													October 21, 2011	October 31, 2011		November 14, 2011	0.3375			4,990			5
													January 24, 2012	February 3, 2012		February 14, 2012	0.35			7,735			10
													April 18, 2012	April 30, 2012		May 15, 2012	0.3625			9,165			10
													July 24, 2012	August 3, 2012		August 14, 2012	0.4125			13,574			134
													October 17, 2012	October 29, 2012		November 14, 2012	0.45			22,846			707
													January 24, 2013	February 4, 2013		February 14, 2013	0.4625			24,245			927
													April 25, 2013	May 6, 2013		May 15, 2013	0.4775			25,605			1,189
													July 25, 2013	August 5, 2013		August 14, 2013	0.4938			31,725			1,739
													October 23, 2013	November 4, 2013		November 14, 2013	0.5113			35,908			2,491
													January 23, 2014	February 4, 20143		February 14, 2014	0.5313			42,150			4,283
													April 24, 2014	May 5, 2014		May 15, 2014	0.5513			43,737			5,754
Future Distribution Payments
Partnership Equity
Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner
									Marginal Percentage Interest In												Marginal Percentage Interest In
		Total Quarterly							Distributions					Total Quarterly							Distributions
		Distribution Per Unit							Unitholders		General Partner			Distribution per Unit							Unitholders		General Partner
	Minimum quarterly distribution						$	0.3375	99.9	%	0.1	%	Minimum quarterly distribution						$ 0.337500		99.9	%	0.1	%
	First target distribution	above		$	0.3375	up to	$	0.388125	99.9	%	0.1	%	First target distribution	above		$ 0.337500	up to		$ 0.388125		99.9	%	0.1	%
	Second target distribution	above		$	0.388125	up to	$	0.421875	86.9	%	13.1	%	Second target distribution	above		$ 0.388125	up to		$ 0.421875		86.9	%	13.1	%
	Third target distribution	above		$	0.421875	up to	$	0.50625	76.9	%	23.1	%	Third target distribution	above		$ 0.421875	up to		$ 0.506250		76.9	%	23.1	%
	Thereafter	above		$	0.50625				51.9	%	48.1	%	Thereafter	above		$ 0.506250					51.9	%	48.1	%

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Fair Value of Financial Instruments
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 on the condensed consolidated balance sheet at September 30, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2014:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	48,632		$	(5,378	)					Level 1 measurements	$	4,990		$	(3,258	)
	Level 2 measurements		51,389			(38,280		)					Level 2 measurements	49,605			(43,303		)
			100,021			(43,658		)						54,595			(46,561		)
	Netting of counterparty contracts (1)		(4,635		)	4,635							Netting of counterparty contracts(1)	(4,347		)	4,347
	Cash collateral held		(13,704		)	—							Cash collateral provided or held	456			—
	Commodity derivatives on condensed consolidated balance sheet		$	81,682		$	(39,023	)					Commodity contracts reported on consolidated balance sheet	$	50,704		$	(42,214	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at March 31, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2013:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	4,990		$	(3,258	)					Level 1 measurements	$	947		$	(3,324	)
	Level 2 measurements		49,605			(43,303		)					Level 2 measurements	9,911			(13,280		)
			54,595			(46,561		)						10,858			(16,604		)
	Netting of counterparty contracts (1)		(4,347		)	4,347							Netting of counterparty contracts(1)	(3,503		)	3,503
	Net cash collateral provided		456			—							Cash collateral provided or held	(1,760		)	400
	Commodity derivatives on condensed consolidated balance sheet		$	50,704		$	(42,214	)					Commodity contracts reported on consolidated balance sheet	$	5,595		$	(12,701	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
Schedule of location of commodity derivative assets (liabilities) reported on the consolidated balance sheets
			September 30,			March 31,								March 31,
			2014			2014								2014			2013
			(in thousands)											(in thousands)
	Prepaid expenses and other current assets		$	81,682		$	50,704						Prepaid expenses and other current assets	$	50,704		$	5,551
	Accrued expenses and other payables		(39,023		)	(42,214		)					Other noncurrent assets	—			44
	Net commodity derivative asset		$	42,659		$	8,490						Accrued expenses and other payables	(42,214		)	(12,701		)
													Net asset (liability)	$	8,490		$	(7,106	)
Schedule of open commodity derivative contract positions
					Total		Fair Value						Contracts	Settlement Period		Total		Fair Value
					Notional		of									Notional		of Net Assets
					Units		Net Assets									Units		(Liabilities)
	Contracts		Settlement Period		(Barrels)		(Liabilities)									(Barrels)
					(in thousands)											(in thousands)
	At September 30, 2014 -												At March 31, 2014 -
	Cross-commodity (1)		October 2014 – March 2015		(12	)	$	(1,283	)				Cross-commodity (1)	April 2014 – March 2015		140		$	(1,876	)
	Crude oil fixed-price (2)		October 2014 – December 2015		(1,638	)	9,380						Crude oil fixed-price (2)	April 2014 – March 2015		(1,600	)	(2,796		)
	Crude oil index (3)		October 2014 – July 2015		2,195		4,397						Crude oil index (3)	April 2014 – December 2015		3,598		6,099
	Propane fixed-price (4)		October 2014 – March 2015		1,238		53						Propane fixed-price (4)	April 2014 – March 2015		60		1,753
	Refined products fixed-price (5)		October 2014 – July 2015		(4,475	)	38,712						Refined products fixed-price (5)	April 2014 – July 2014		732		560
	Renewable products fixed-price (6)		October 2014 – December 2015		(14	)	5,104						Renewable products fixed-price (6)	April 2014 – July 2014		106		4,084
							56,363						Other	April 2014		—		210
	Net cash collateral held						(13,704		)									8,034
	Net commodity derivatives on condensed consolidated balance sheet						$	42,659					Net cash collateral provided					456
													Net value of commodity derivatives on consolidated balance sheet					$	8,490
	At March 31, 2014 -
	Cross-commodity (1)		April 2014 – March 2015		140		$	(1,876	)				At March 31, 2013 -
	Crude oil fixed-price (2)		April 2014 – March 2015		(1,600	)	(2,796		)				Cross-commodity (1)	April 2013 - March 2014		430		$	(10,208	)
	Crude oil index (3)		April 2014 – December 2015		3,598		6,099						Crude oil fixed-price (2)	April 2013 - March 2014		(144	)	1,033
	Propane fixed-price (4)		April 2014 – March 2015		60		1,753						Crude oil index (3)	April 2013 - June 2014		(91	)	153
	Refined products fixed-price (5)		April 2014 – July 2014		732		560						Propane fixed-price (4)	April 2013 - March 2014		(282	)	3,197
	Renewable products fixed-price (6)		April 2014 – July 2014		106		4,084						Other	May 2013 - June 2013		8		79
	Other		April 2014		—		210											(5,746		)
							8,034						Net cash collateral held					(1,360		)
	Net cash collateral provided						456						Net value of commodity derivatives on consolidated balance sheet					$	(7,106	)
	Net commodity derivatives on condensed consolidated balance sheet						$	8,490
													(1)         Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as economic hedges against the risk of one commodity price moving relative to another commodity price.
	(1)     Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price.
													(2)         Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
	(2)     Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
													(3)         Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
	(3)     Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
													(4)         Propane fixed-price — Our liquids segment routinely purchases inventory during the warmer months and stores the inventory for sale in the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
	(4)     Propane fixed-price — Our liquids segment routinely purchases propane inventory during the warmer months and stores the propane inventory for sale during the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
													(5)         Refined products fixed-price — Our refined products segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
	(5)     Refined products fixed-price — Our refined products and renewables segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
													(6)         Renewable products fixed-price — Our renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
	(6)     Renewable products fixed-price — Our refined products and renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
Schedule of net gains (losses) from entity's commodity derivatives to cost of sales
	Three Months Ended						Six Months Ended						Year Ended March 31,
	September 30,						September 30,						2014	$	(43,655	)
	2014			2013			2014			2013			2013	(4,381		)
	(in thousands)												2012	5,676
	$	55,981		$	(10,672	)	$	38,496		$	(17,881	)

Segments_Tables

Segments (Tables)	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Segments
Schedule of certain information related to the results of operations of each segment
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands)
		(in thousands)												Revenues:
	Revenues:													Crude oil logistics -
	Crude oil logistics -													Crude oil sales	$	4,559,923		$	2,322,706		$	—
	Crude oil sales	$	2,108,117		$	1,013,061		$	4,035,061		$	1,941,595		Crude oil transportation and other	36,469			16,442			—
	Crude oil transportation and other	13,082			9,794			25,196			19,729			Water solutions -
	Water solutions -													Water treatment and disposal	125,788			54,334			—
	Water treatment and disposal	47,572			28,823			89,288			47,511			Water transportation	17,312			7,893			—
	Water transportation	5,147			5,367			10,745			7,192			Liquids -
	Liquids -													Propane sales	1,632,948			841,448			923,022
	Propane sales	240,433			191,437			462,879			315,274			Other product sales	1,231,965			858,276			251,627
	Other product sales	306,625			308,606			594,984			558,459			Other revenues	31,062			33,954			2,462
	Other revenues	6,814			9,250			12,530			18,114			Retail propane -
	Retail propane -													Propane sales	388,225			288,410			175,417
	Propane sales	48,552			40,651			100,578			87,342			Distillate sales	127,672			106,192			6,547
	Distillate sales	11,530			10,562			30,225			28,431			Other revenues	35,918			35,856			17,370
	Other revenues	8,276			8,198			15,457			15,898			Refined products	1,180,895			—			—
	Refined products and renewables -													Renewables	176,781			—			—
	Refined products sales	2,489,795			—			3,476,018			—			Corporate and other	437,713			4,233			—
	Renewables sales	117,425			—			248,699			—			Eliminations of intersegment sales	(283,397		)	(151,977		)	(65,972		)
	Corporate and other	1,333			1,485			2,794			2,959			Total revenues	$	9,699,274		$	4,417,767		$	1,310,473
	Elimination of intersegment sales	(24,175		)	(33,297		)	(75,314		)	(62,610		)
	Total revenues	$	5,380,526		$	1,593,937		$	9,029,140		$	2,979,894			Year Ended March 31,
															2014			2013			2012
	Depreciation and Amortization:														(in thousands)
	Crude oil logistics	$	9,240		$	3,330		$	18,971		$	8,014		Depreciation and amortization:
	Water solutions	17,573			11,438			34,665			18,794			Crude oil logistics	$	22,111		$	9,176		$	—
	Liquids	3,384			2,672			6,585			5,376			Water solutions	55,105			20,923			—
	Retail propane	7,684			6,871			15,255			14,111			Liquids	11,018			11,085			3,661
	Refined products and renewables	11,917			—			12,761			—			Retail propane	28,878			25,496			11,450
	Corporate and other	301			750			1,237			1,490			Refined products	109			—			—
	Total depreciation and amortization	$	50,099		$	25,061		$	89,474		$	47,785		Renewables	516			—			—
														Corporate and other	3,017			2,173			—
	Operating Income (Loss):													Total depreciation and amortization	$	120,754		$	68,853		$	15,111
	Crude oil logistics	$	38		$	5,884		$	1,501		$	12,493
	Water solutions	14,792			2,913			13,885			5,956				Year Ended March 31,
	Liquids	10,929			14,605			10,016			12,490				2014			2013			2012
	Retail propane	(3,062		)	(4,520		)	(4,648		)	(6,024		)		(in thousands)
	Refined products and renewables	8,822			—			7,567			—			Operating income (loss):
	Corporate and other	(23,749		)	(8,937		)	(41,106		)	(22,312		)	Crude oil logistics	$	678		$	34,236		$	—
	Total operating income (loss)	$	7,770		$	9,945		$	(12,785	)	$	2,603		Water solutions	10,317			8,576			—
														Liquids	71,888			30,336			9,735
														Retail propane	61,285			46,869			9,616
														Refined products	4,080			—			—
														Renewables	2,434			—			—
														Corporate and other	(44,117		)	(32,710		)	(4,321		)
														Total operating income	$	106,565		$	87,307		$	15,030
Schedule of additions to property, plant and equipment for each segment
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands)
		(in thousands)												Additions to property, plant and equipment, including acquisitions (accrual basis):
	Additions to property, plant and equipment:													Crude oil logistics	$	204,642		$	89,860		$	—
	Crude oil logistics	$	39,464		$	31,336		$	81,413		$	35,462		Water solutions	100,877			137,116			—
	Water solutions	40,610			62,473			48,072			70,182			Liquids	52,560			15,129			50,276
	Liquids	1,911			13,209			3,070			28,316			Retail propane	24,430			66,933			150,181
	Retail propane	9,567			4,546			12,411			11,492			Refined products	719			—			—
	Refined products and renewables	512,281			—			512,281			—			Renewables	519			—			—
	Corporate and other	1,809			217			3,262			846			Corporate and other	7,242			17,858			—
	Total	$	605,642		$	111,781		$	660,509		$	146,298		Total	$	390,989		$	326,896		$	200,457
Schedule of long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment
		September 30,			March 31,										March 31,
		2014			2014													2013
		(in thousands)													2014			(Note 2)
	Total assets:														(in thousands)
	Crude oil logistics	$	2,079,380		$	1,723,812								Total assets:
	Water solutions	964,336			875,714									Crude oil logistics	$	1,723,812		$	801,351
	Liquids	756,133			577,795									Water solutions	875,714			466,412
	Retail propane	506,958			541,832									Liquids	577,795			474,141
	Refined products and renewables	2,183,674			303,230									Retail propane	541,832			513,301
	Corporate and other	61,198			144,840									Refined products	157,581			—
	Total	$	6,551,679		$	4,167,223								Renewables	145,649			—
														Corporate and other	144,840			36,413
	Long-lived assets, net:													Total	$	4,167,223		$	2,291,618
	Crude oil logistics	$	996,615		$	980,978
	Water solutions	910,467			848,479									Long-lived assets, net:
	Liquids	271,567			274,846									Crude oil logistics	$	980,978		$	357,230
	Retail propane	436,621			438,324									Water solutions	848,479			453,909
	Refined products and renewables	772,916			60,720									Liquids	274,846			238,192
	Corporate and other	53,705			47,961									Retail propane	438,324			441,762
	Total	$	3,441,891		$	2,651,308								Refined products	27,017			—
														Renewables	33,703			—
														Corporate and other	47,961			31,996
														Total	$	2,651,308		$	1,523,089

Transactions_with_Affiliates_T

Transactions with Affiliates (Tables)	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Transactions with Affiliates
Summary of purchase and sales transactions of products and services
		Three Months Ended				Six Months Ended					Year Ended March 31,
		September 30,				September 30,					2014		2013		2012
		2014		2013		2014		2013			(in thousands)
		(in thousands)								Sales to SemGroup	$	306,780	$	32,431	$	29,200
	Sales to SemGroup	$	43,427	$	3,780	$	117,233	$	3,780	Purchases from SemGroup	445,951		60,425		23,800
	Purchases from SemGroup	45,730		28,377		118,997		47,916		Sales to entities affiliated with management	110,824		16,828		—
	Purchases from equity method investees	34,689		—		70,965		—		Purchases from entities affiliated with management	120,038		60,942		—
	Sales to equity method investees	9,131		—		9,131		—
	Sales to entities affiliated with management	1,706		58,769		1,854		109,872
	Purchases from entities affiliated with management	3,845		48,522		6,984		56,346
Schedule of receivables from affiliates
		September 30,		March 31,							March 31,
		2014		2014							2014		2013
		(in thousands)									(in thousands)
	Receivables from SemGroup	$	39,331	$	7,303					Receivables from entities affiliated with management	$	142	$	22,883
	Receivables from entities affiliated with management	1,705		142						Receivables from SemGroup	7,303		—
	Receivables from equity method investees	670		—							$	7,445	$	22,883
	Total	$	41,706	$	7,445
Schedule of payables to affiliates
		September 30,		March 31,							March 31,
		2014		2014							2014		2013
		(in thousands)									(in thousands)
	Payables to SemGroup	$	44,015	$	27,738					Payables to SemGroup	$	76,192	$	4,601
	Payables to equity method investees	39,549		48,454						Payables to entities affiliated with management	654		2,299
	Payables to entities affiliated with management	1,743		654							$	76,846	$	6,900
	Total	$	85,307	$	76,846

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Mar. 31, 2014
Quarterly Financial Data (Unaudited)
Schedule of summarized unaudited quarterly financial data
		Quarter Ended										Year Ended
		June 30,			September 30,			December 31,		March 31,		March 31,
		2013			2013			2013		2014		2014
		(in thousands, except unit and per unit data)
	Total revenues	$	1,385,957		$	1,593,937		$	2,743,445	$	3,975,935	$	9,699,274
	Total cost of sales	$	1,303,076		$	1,488,850		$	2,576,029	$	3,764,744	$	9,132,699
	Net income (loss)	$	(17,508	)	$	(932	)	$	24,052	$	43,146	$	48,758
	Net income (loss) attributable to parent equity	$	(17,633	)	$	(941	)	$	23,898	$	42,331	$	47,655
	Earnings (loss) per unit, basic and diluted -
	Common units	$	(0.35	)	$	(0.05	)	$	0.27	$	0.46	$	0.51
	Subordinated units	$	(0.46	)	$	(0.09	)	$	0.23	$	0.46	$	0.32
	Weighted average common units outstanding - basic and diluted	47,703,313			58,909,389			67,941,726		73,421,309		61,970,471
	Weighted average subordinated outstanding units - basic and diluted	5,919,346			5,919,346			5,919,346		5,919,346		5,919,346
		Quarter Ended										Year Ended
		June 30,			September 30,			December 31,		March 31,		March 31,
		2012			2012			2012		2013		2013
		(in thousands, except unit and per unit data)
	Total revenues	$	326,436		$	1,135,510		$	1,338,208	$	1,617,613	$	4,417,767
	Total cost of sales	$	298,985		$	1,053,690		$	1,204,545	$	1,481,890	$	4,039,110
	Net income (loss)	$	(24,710	)	$	10,082		$	40,477	$	22,341	$	48,190
	Net income (loss) attributable to parent equity	$	(24,650	)	$	10,073		$	40,176	$	22,341	$	47,940
	Earnings (loss) per unit, basic and diluted -
	Common units	$	(0.76	)	$	0.18		$	0.75	$	0.39	$	0.96
	Subordinated units	$	(0.77	)	$	0.18		$	0.75	$	0.39	$	0.93
	Weighted average common units outstanding - basic and diluted	26,529,133			44,831,836			46,364,381		47,665,015		41,353,574
	Weighted average subordinated outstanding units - basic and diluted	5,919,346			5,919,346			5,919,346		5,919,346		5,919,346

Condensed_Consolidating_Guaran1

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Tables)	6 Months Ended																			12 Months Ended
	Sep. 30, 2014																			Mar. 31, 2014
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Schedule of Condensed Consolidating Balance Sheets
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Balance Sheet																			Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		September 30, 2014																			March 31, 2014
		NGL Energy			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
		Partners LP																			Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	ASSETS																			ASSETS
	CURRENT ASSETS:																			CURRENT ASSETS:
	Cash and cash equivalents	$	2,841		$	—		$	7,823		$	1,159		$	—		$	11,823		Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			1,419,442			13,675			—			1,433,117			Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904
	Accounts receivable - affiliates	—			—			41,035			671			—			41,706			Accounts receivable - affiliates	—			—			7,445			—			—			7,445
	Inventories	—			—			937,814			3,775			—			941,589			Inventories	—			—			306,434			3,726			—			310,160
	Prepaid expenses and other current assets	—			—			155,332			1,486			—			156,818			Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	2,841			—			2,561,446			20,766			—			2,585,053			Total current assets	1,181			—			1,290,690			17,428			—			1,309,299
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			863,694			569,619			—			1,433,313			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346
	GOODWILL	—			—			1,139,374			31,116			—			1,170,490			GOODWILL	—			—			1,105,008			1,998			—			1,107,006
	INTANGIBLE ASSETS, net of accumulated amortization	1,307			17,619			778,960			40,202			—			838,088			INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956
	INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			214,234			268,410			—			482,644			INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821
	NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893			849,526			(1,026,605		)	(71,814		)	—			—			NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—
	INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573			—			10,470			—			(1,754,043		)	—			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
	OTHER NONCURRENT ASSETS	—			—			40,035			2,056			—			42,091			OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795
	Total assets	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679		Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	LIABILITIES AND EQUITY																			LIABILITIES AND EQUITY
	CURRENT LIABILITIES:																			CURRENT LIABILITIES:
	Accounts payable - trade	$	—		$	—		$	1,333,780		$	11,244		$	—		$	1,345,024		Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211
	Accounts payable - affiliates	—			—			85,237			70			—			85,307			Accounts payable - affiliates	—			—			73,703			3,143			—			76,846
	Accrued expenses and other payables	554			19,021			186,226			12,681			—			218,482			Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690
	Advance payments received from customers	—			—			105,597			508			—			106,105			Advance payments received from customers	—			—			29,891			74			—			29,965
	Current maturities of long-term debt	—			—			5,004			58			—			5,062			Current maturities of long-term debt	—			—			7,058			22			—			7,080
	Total current liabilities	554			19,021			1,715,844			24,561			—			1,759,980			Total current liabilities	554			14,266			961,827			19,145			—			995,792
	LONG-TERM DEBT, net of current maturities	250,000			850,000			1,085,155			252,196			—			2,437,351			LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834
	OTHER NONCURRENT LIABILITIES	—			—			35,160			4,358			—			39,518			OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744
																				EQUITY
	EQUITY																			Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815
	Partners’ equity (deficit)	1,746,060			(1,876		)	1,745,450			579,312			(2,322,813		)	1,746,133			Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
	Accumulated other comprehensive loss	—			—			(1		)	(72		)	—			(73		)	Noncontrolling interests	—			—			—			—			5,274			5,274
	Noncontrolling interests	—			—			—			—			568,770			568,770			Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
	Total equity (deficit)	1,746,060			(1,876		)	1,745,449			579,240			(1,754,043		)	2,314,830			Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	Total liabilities and equity	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679
																				(1)   The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)         The parent is a co-issuer of the 2019 Notes and 2021 Notes that are included in the NGL Energy Finance Corp. column.																			NGL ENERGY PARTNERS LP
																				Condensed Consolidating Balance Sheet
	NGL ENERGY PARTNERS LP																			(U.S. Dollars in Thousands)
	Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																				March 31, 2013
																					NGL Energy
		March 31, 2014																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		NGL Energy																			(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						ASSETS
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			CURRENT ASSETS:
	ASSETS																			Cash and cash equivalents	$	—		$	11,206		$	355		$	—		$	11,561
	CURRENT ASSETS:																			Accounts receivable - trade, net of allowance for doubtful accounts	—			561,560			1,197			—			562,757
	Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440		Accounts receivable - affiliates	—			22,883			—			—			22,883
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904			Inventories	—			126,024			871			—			126,895
	Accounts receivable - affiliates	—			—			7,445			—			—			7,445			Prepaid expenses and other current assets	—			37,784			107			—			37,891
	Inventories	—			—			306,434			3,726			—			310,160			Total current assets	—			759,457			2,530			—			761,987
	Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	1,181			—			1,290,690			17,428			—			1,309,299			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			497,743			28,694			—			526,437
																				GOODWILL	—			553,222			1,998			—			555,220
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346			INTANGIBLE ASSETS, net of accumulated amortization	717			439,365			1,350			—			441,432
	GOODWILL	—			—			1,105,008			1,998			—			1,107,006			NET INTERCOMPANY RECEIVABLES (PAYABLES)	237,736			(233,294		)	(4,442		)	—			—
	INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	895,779			20,371			—			(916,150		)	—
INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821			OTHER NONCURRENT ASSETS	—			6,542			—			—			6,542
NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—			Total assets	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795			LIABILITIES AND EQUITY
Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		CURRENT LIABILITIES:
																			Accounts payable - trade	$	—		$	534,164		$	1,891		$	—		$	536,055
LIABILITIES AND EQUITY																			Accounts payable - affiliates	—			6,900			—			—			6,900
CURRENT LIABILITIES:																			Accrued expenses and other payables	554			83,001			2,051			—			85,606
Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211		Advance payments received from customers	—			22,364			8			—			22,372
Accounts payable - affiliates	—			—			73,703			3,143			—			76,846			Current maturities of long-term debt	—			8,610			16			—			8,626
Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690			Total current liabilities	554			655,039			3,966			—			659,559
Advance payments received from customers	—			—			29,891			74			—			29,965
Current maturities of long-term debt	—			—			7,058			22			—			7,080			LONG-TERM DEBT, net of current maturities	250,000			490,433			3			—			740,436
Total current liabilities	554			14,266			961,827			19,145			—			995,792			OTHER NONCURRENT LIABILITIES	—			2,155			50			—			2,205
																			EQUITY
LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834			Partners’ equity	883,678			895,779			26,087			(921,890		)	883,654
OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744			Accumulated other comprehensive income	—			—			24			—			24
																			Noncontrolling interests	—			—			—			5,740			5,740
EQUITY																			Total equity	883,678			895,779			26,111			(916,150		)	889,418
Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815			Total liabilities and equity	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
Noncontrolling interests	—			—			—			—			5,274			5,274
Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
(1)     The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.
Schedule of Condensed Consolidating Statements of Operations	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			Condensed Consolidating Statement of Operations
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	REVENUES	$	—		$	—		$	5,325,186		$	55,364		$	(24	)	$	5,380,526		REVENUES	$	—		$	—		$	9,560,124		$	139,519		$	(369	)	$	9,699,274
	COST OF SALES	—			—			5,161,935			17,554			(24		)	5,179,465			COST OF SALES	—			—			9,011,011			122,057			(369		)	9,132,699
	OPERATING COSTS AND EXPENSES:																			OPERATING COSTS AND EXPENSES:
	Operating	—			—			84,300			17,253			—			101,553			Operating	—			—			253,214			6,182			—			259,396
	General and administrative	—			—			36,360			5,279			—			41,639			General and administrative	—			—			77,756			2,104			—			79,860
	Depreciation and amortization	—			—			38,999			11,100			—			50,099			Depreciation and amortization	—			—			117,573			3,181			—			120,754
	Operating Income	—			—			3,592			4,178			—			7,770			Operating Income	—			—			100,570			5,995			—			106,565
	OTHER INCOME (EXPENSE):																			OTHER INCOME (EXPENSE):
	Earnings of unconsolidated entities	—			—			2,310			1,387			—			3,697			Earnings from unconsolidated entities	—			—			1,898			—			—			1,898
	Interest expense	(4,067		)	(13,134		)	(9,956		)	(1,506		)	12			(28,651		)	Interest expense	(16,818		)	(15,000		)	(27,031		)	(51		)	46			(58,854		)
	Other, net	—			—			(524		)	(81		)	(12		)	(617		)	Other, net	—			—			202			(70		)	(46		)	86
	Income (Loss) Before Income Taxes	(4,067		)	(13,134		)	(4,578		)	3,978			—			(17,801		)	Income (Loss) Before Income Taxes	(16,818		)	(15,000		)	75,639			5,874			—			49,695
	INCOME TAX (PROVISION) BENEFIT	—			—			1,951			(29		)	—			1,922			INCOME TAX PROVISION	—			—			(937		)	—			—			(937		)
	EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(15,157		)	—			604			—			14,553			—			EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	64,473			—			4,771			—			(69,244		)	—
	Net Income (Loss)	(19,224		)	(13,134		)	(2,023		)	3,949			14,553			(15,879		)	Net Income (Loss)	47,655			(15,000		)	79,473			5,874			(69,244		)	48,758
	LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(11,056		)	(11,056		)	NET INCOME ALLOCATED TO GENERAL PARTNER													(14,148		)	(14,148		)
	LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,345		)	(3,345		)	NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(1,103		)	(1,103		)
	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	152		$	(30,280	)	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(84,495	)	$	33,507
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			Condensed Consolidating Statement of Operations
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2013																			Year Ended March 31, 2013
		NGL Energy																			NGL Energy
		Partners LP			Guarantor			Non-Guarantor			Consolidating										Partners LP			Guarantor			Non-Guarantor			Consolidating
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated							(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	REVENUES	$	—		$	1,546,226		$	47,735		$	(24	)	$	1,593,937					REVENUES	$	—		$	4,409,198		$	8,878		$	(309	)	$	4,417,767
	COST OF SALES	—			1,445,442			43,432			(24		)	1,488,850						COST OF SALES	—			4,038,251			1,168			(309		)	4,039,110
	OPERATING COSTS AND EXPENSES:																			OPERATING COSTS AND EXPENSES:
	Operating	—			52,979			2,790			—			55,769						Operating	—			164,944			4,855			—			169,799
	General and administrative	—			14,089			223			—			14,312						General and administrative	—			52,461			237			—			52,698
	Depreciation and amortization	—			23,970			1,091			—			25,061						Depreciation and amortization	—			66,916			1,937			—			68,853
	Operating Income	—			9,746			199			—			9,945						Operating Income	—			86,626			681			—			87,307
	OTHER INCOME (EXPENSE):																			OTHER INCOME (EXPENSE):
	Interest expense	(4,179		)	(6,880		)	(13		)	12			(11,060		)				Interest expense	(13,041		)	(19,951		)	(48		)	46			(32,994		)
	Other, net	—			528			(97		)	(12		)	419						Loss on early extinguishment of debt	—			(5,769		)	—			—			(5,769		)
																				Other, net	—			1,666			(99		)	(46		)	1,521
	Income (Loss) Before Income Taxes	(4,179		)	3,394			89			—			(696		)
																				Income (Loss) Before Income Taxes	(13,041		)	62,572			534			—			50,065
	INCOME TAX PROVISION	—			(236		)	—			—			(236		)
																				INCOME TAX PROVISION	—			(1,875		)	—			—			(1,875		)
	EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	3,238			80			—			(3,318		)	—
																				EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	60,981			284			—			(61,265		)	—
	Net Income (Loss)	(941		)	3,238			89			(3,318		)	(932		)
																				Net Income	47,940			60,981			534			(61,265		)	48,190
	LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(2,451		)	(2,451		)
																				NET INCOME ALLOCATED TO GENERAL PARTNER										(2,917		)	(2,917		)
	LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(9		)	(9		)
																				NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(250		)	(250		)
	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(941	)	$	3,238		$	89		$	(5,778	)	$	(3,392	)
																				NET INCOME ALLOCATED TO LIMITED PARTNERS	$	47,940		$	60,981		$	534		$	(64,432	)	$	45,023
	NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			NGL ENERGY PARTNERS LP
	(U.S. Dollars in Thousands)																			Condensed Consolidating Statement of Operations
																				(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2014
		NGL Energy																			Year Ended March 31, 2012
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				Partners LP			Guarantor			Non-Guarantor			Consolidating
																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
REVENUES	$	—		$	—		$	8,952,772		$	76,421		$	(53	)	$	9,029,140
																			REVENUES	$	—		$	1,310,473		$	225		$	(225	)	$	1,310,473
COST OF SALES	—			—			8,676,881			36,690			(53		)	8,713,518
																			COST OF SALES	—			1,217,248			—			(225		)	1,217,023
OPERATING COSTS AND EXPENSES:
Operating	—			—			150,919			18,502			—			169,421			OPERATING COSTS AND EXPENSES:
General and administrative	—			—			64,124			5,388			—			69,512			Operating	—			47,162			138			—			47,300
Depreciation and amortization	—			—			77,545			11,929			—			89,474			General and administrative	—			15,823			186			—			16,009
																			Depreciation and amortization	—			14,964			147			—			15,111
Operating Income (Loss)	—			—			(16,697		)	3,912			—			(12,785		)
																			Operating Income (Loss)	—			15,276			(246		)	—			15,030
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	—			—			4,875			1,387			—			6,262			OTHER INCOME (EXPENSE):
Interest expense	(8,313		)	(21,280		)	(18,058		)	(1,517		)	23			(49,145		)	Interest expense	—			(7,619		)	(46		)	45			(7,620		)
Other, net	—			—			(1,056		)	71			(23		)	(1,008		)	Other, net	—			1,100			—			(45		)	1,055
Income (Loss) Before Income Taxes	(8,313		)	(21,280		)	(30,936		)	3,853			—			(56,676		)	Income (Loss) Before Income Taxes	—			8,757			(292		)	—			8,465
INCOME TAX (PROVISION) BENEFIT	—			—			993			(106		)	—			887			INCOME TAX PROVISION	—			(601		)	—			—			(601		)
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(50,886		)	—			337			—			50,549			—			EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	7,876			(280		)	—			(7,596		)	—
Net Income (Loss)	(59,199		)	(21,280		)	(29,606		)	3,747			50,549			(55,789		)	Net Income (Loss)	7,876			7,876			(292		)	(7,596		)	7,864
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(20,437		)	(20,437		)	NET INCOME ALLOCATED TO GENERAL PARTNER										(8		)	(8		)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,410		)	(3,410		)	NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS										12			12
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	26,702		$	(79,636	)	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	7,876		$	7,876		$	(292	)	$	(7,592	)	$	7,868
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2013
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor			Consolidating
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
REVENUES	$	—		$	2,914,531		$	65,421		$	(58	)	$	2,979,894
COST OF SALES	—			2,735,890			56,094			(58		)	2,791,926
OPERATING COSTS AND EXPENSES:
Operating	—			99,710			5,104			—			104,814
General and administrative	—			32,297			469			—			32,766
Depreciation and amortization	—			46,000			1,785			—			47,785
Operating Income	—			634			1,969			—			2,603
OTHER INCOME (EXPENSE):
Interest expense	(8,368		)	(13,309		)	(28		)	23			(21,682		)
Other, net	—			627			(135		)	(23		)	469
Income (Loss) Before Income Taxes	(8,368		)	(12,048		)	1,806			—			(18,610		)
INCOME TAX BENEFIT	—			170			—			—			170
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(10,206		)	1,672			—			8,534			—
Net Income (Loss)	(18,574		)	(10,206		)	1,806			8,534			(18,440		)
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(4,139		)	(4,139		)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(134		)	(134		)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(18,574	)	$	(10,206	)	$	1,806		$	4,261		$	(22,713	)
Schedule of Condensed Consolidating Statements of Comprehensive Income (Loss)	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statements of Comprehensive Income (Loss)																			Condensed Consolidating Statements of Comprehensive Income (Loss)
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	Net income (loss)	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	14,553		$	(15,879	)	Net income (loss)	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(69,244	)	$	48,758
	Other comprehensive income (loss)	—			—			4			(26		)	—			(22		)	Other comprehensive loss, net of tax	—			—			(189		)	(71		)	—			(260		)
	Comprehensive income (loss)	$	(19,224	)	$	(13,134	)	$	(2,019	)	$	3,923		$	14,553		$	(15,901	)	Comprehensive income (loss)	$	47,655		$	(15,000	)	$	79,284		$	5,803		$	(69,244	)	$	48,498
																				(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
																					Year Ended March 31, 2013
		Three Months Ended September 30, 2013																			NGL Energy
		NGL Energy																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		Partners LP			Guarantor			Non-Guarantor			Consolidating										(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
																				Net income	$	47,940		$	60,981		$	534		$	(61,265	)	$	48,190
	Net income (loss)	$	(941	)	$	3,238		$	89		$	(3,318	)	$	(932	)
																				Other comprehensive loss, net of tax	—			—			(7		)	—			(7		)
	Other comprehensive loss	—			—			(5		)	—			(5		)
																				Comprehensive income	$	47,940		$	60,981		$	527		$	(61,265	)	$	48,183
	Comprehensive income (loss)	$	(941	)	$	3,238		$	84		$	(3,318	)	$	(937	)
																					Year Ended March 31, 2012
	NGL ENERGY PARTNERS LP																				NGL Energy
	Condensed Consolidating Statements of Comprehensive Income (Loss)																				Partners LP			Guarantor			Non-Guarantor			Consolidating
	(U.S. Dollars in Thousands)																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Six Months Ended September 30, 2014																		Net income (loss)	$	7,876		$	7,876		$	(292	)	$	(7,596	)	$	7,864
		NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						Other comprehensive loss, net of tax	—			—			(25		)	—			(25		)
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
																				Comprehensive income (loss)	$	7,876		$	7,876		$	(317	)	$	(7,596	)	$	7,839
	Net income (loss)	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	50,549		$	(55,789	)
	Other comprehensive income (loss)	—			—			189			(26		)	—			163
	Comprehensive income (loss)	$	(59,199	)	$	(21,280	)	$	(29,417	)	$	3,721		$	50,549		$	(55,626	)
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
		Six Months Ended September 30, 2013
		NGL Energy
		Partners LP			Guarantor			Non-Guarantor			Consolidating
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	Net income (loss)	$	(18,574	)	$	(10,206	)	$	1,806		$	8,534		$	(18,440	)
	Other comprehensive loss	—			—			(30		)	—			(30		)
	Comprehensive income (loss)	$	(18,574	)	$	(10,206	)	$	1,776		$	8,534		$	(18,470	)
Schedule of Condensed Consolidating Statements of Cash Flows	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Cash Flows																			Condensed Consolidating Statement of Cash Flows
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor										Partners LP			NGL Energy			Guarantor			Non-Guarantor
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated							(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated
	OPERATING ACTIVITIES:																			OPERATING ACTIVITIES:
	Net cash provided by (used in) operating activities	$	(8,180	)	$	(15,383	)	$	(56,019	)	$	17,947		$	(61,635	)				Net cash provided by (used in) operating activities	$	(16,625	)	$	—		$	99,754		$	2,107		$	85,236
	INVESTING ACTIVITIES:																			INVESTING ACTIVITIES:
	Purchases of long-lived assets	—			—			(81,710		)	(1,141		)	(82,851		)				Purchases of long-lived assets	—			—			(118,455		)	(46,693		)	(165,148		)
	Acquisitions of businesses, including acquired working capital, net of cash acquired	—			—			(657,514		)	(1,250		)	(658,764		)				Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,154		)	—			(932,373		)	(2,283		)	(1,268,810		)
	Cash flows from commodity derivatives	—			—			4,327			—			4,327						Cash flows from commodity derivatives	—			—			(35,956		)	—			(35,956		)
	Proceeds from sales of assets	—			—			8,741			—			8,741						Proceeds from sales of assets	—			—			12,884			11,776			24,660
	Investments in unconsolidated entities	—			—			(6,106		)	(20,284		)	(26,390		)				Investments in unconsolidated entities	—			—			(11,515		)	—			(11,515		)
	Distributions of capital from unconsolidated entities	—			—			2,774			1,875			4,649						Distributions of capital from unconsolidated entities	—			—			1,591			—			1,591
	Net cash used in investing activities	—			—			(729,488		)	(20,800		)	(750,288		)				Other	—			—			540			(735		)	(195		)
																				Net cash used in investing activities	(334,154		)	—			(1,083,284		)	(37,935		)	(1,455,373		)
	FINANCING ACTIVITIES:
	Proceeds from borrowings under revolving credit facilities	—			—			1,923,500			56,000			1,979,500						FINANCING ACTIVITIES:
	Payments on revolving credit facilities	—			—			(1,766,000		)	(38,000		)	(1,804,000		)				Proceeds from borrowings under revolving credit facilities	—			—			2,545,500			—			2,545,500
	Issuance of notes	—			400,000			—			—			400,000						Payments on revolving credit facilities	—			—			(2,101,000		)	—			(2,101,000		)
	Payments on other long-term debt	—			—			(4,173		)	(2		)	(4,175		)				Issuances of notes	—			450,000			—			—			450,000
	Debt issuance costs	(269		)	(7,209		)	(1,720		)	—			(9,198		)				Proceeds from borrowings on other long-term debt	—			—			780			100			880
	Contributions	395			—			—			—			395						Payments on other long-term debt	—			—			(8,802		)	(17		)	(8,819		)
	Distributions to owners	(111,008		)	—			—			—			(111,008		)				Debt issuance costs	(645		)	(12,286		)	(11,664		)	—			(24,595		)
	Distributions to noncontrolling interest partners	—			—			—			(8,654		)	(8,654		)				Contributions	765			—			—			2,060			2,825
	Proceeds from sale of common units, net of offering costs	370,446			—			—			—			370,446						Distributions	(145,090		)	—			—			(840		)	(145,930		)
	Net changes in advances with consolidated entities	(249,724		)	(377,408		)	632,995			(5,863		)	—						Proceeds from sale of common units, net of offering costs	650,155			—			—			—			650,155
	Net cash provided by financing activities	9,840			15,383			784,602			3,481			813,306						Net changes in advances with consolidated entities	(153,225		)	(437,714		)	556,238			34,701			—
	Net increase (decrease) in cash and cash equivalents	1,660			—			(905		)	628			1,383						Net cash provided by financing activities	351,960			—			981,052			36,004			1,369,016
	Cash and cash equivalents, beginning of period	1,181			—			8,728			531			10,440						Net increase (decrease) in cash and cash equivalents	1,181			—			(2,478		)	176			(1,121		)
	Cash and cash equivalents, end of period	$	2,841		$	—		$	7,823		$	1,159		$	11,823					Cash and cash equivalents, beginning of period	—			—			11,206			355			11,561
																				Cash and cash equivalents, end of period	$	1,181		$	—		$	8,728		$	531		$	10,440
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Cash Flows																			Condensed Consolidating Statement of Cash Flows
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2013																			Year Ended March 31, 2013
		NGL Energy																			NGL Energy
		Partners LP			Guarantor			Non-Guarantor													Partners LP			Guarantor			Non-Guarantor
		(Parent)			Subsidiaries			Subsidiaries			Consolidated										(Parent)			Subsidiaries			Subsidiaries			Consolidated
	OPERATING ACTIVITIES:																			OPERATING ACTIVITIES:
	Net cash provided by (used in) operating activities	$	(8,312	)	$	(44,607	)	$	4,175		$	(48,744	)							Net cash provided by (used in) operating activities	$	(12,428	)	$	140,794		$	4,268		$	132,634
	INVESTING ACTIVITIES:																			INVESTING ACTIVITIES:
	Purchases of long-lived assets	—			(37,180		)	(30,219		)	(67,399		)							Purchases of long-lived assets	—			(59,903		)	(12,572		)	(72,475		)
	Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,085		)	(56,237		)	(2,283		)	(392,605		)							Acquisitions of businesses, including acquired working capital, net of cash acquired	(452,087		)	(38,718		)	—			(490,805		)
	Cash flows from commodity derivatives	—			(19,074		)	—			(19,074		)							Cash flows from commodity derivatives	—			11,579			—			11,579
	Proceeds from sales of assets	—			2,223			1			2,224									Proceeds from sales of assets	—			5,080			—			5,080
	Net cash used in investing activities	(334,085		)	(110,268		)	(32,501		)	(476,854		)							Net cash used in investing activities	(452,087		)	(81,962		)	(12,572		)	(546,621		)
	FINANCING ACTIVITIES:																			FINANCING ACTIVITIES:
	Proceeds from borrowings under revolving credit facility	—			1,061,500			—			1,061,500									Proceeds from borrowings under revolving credit facilities	—			1,227,975			—			1,227,975
	Payments on revolving credit facility	—			(893,000		)	—			(893,000		)							Payments on revolving credit facilities	—			(964,475		)	—			(964,475		)
	Proceeds from borrowings on other long-term debt	—			780			100			880									Issuance of notes	250,000			—			—			250,000
	Payments on other long-term debt	—			(4,499		)	(8		)	(4,507		)							Proceeds from borrowings on other long-term debt	—			634			19			653
	Debt issuance costs	(133		)	(2,085		)	—			(2,218		)							Payments on other long-term debt	—			(4,837		)	—			(4,837		)
	Contributions	504			—			1,940			2,444									Debt issuance costs	(777		)	(19,412		)	—			(20,189		)
	Distributions to owners	(60,258		)	—			(365		)	(60,623		)							Contributions	510			—			403			913
	Proceeds from sale of common units, net of offering costs	415,089			—			—			415,089									Distributions	(71,608		)	—			(74		)	(71,682		)
	Net changes in advances with consolidated entities	(11,459		)	(15,123		)	26,582			—									Proceeds from sale of common units, net of offering costs	(642		)	—			—			(642		)
	Net cash provided by financing activities	343,743			147,573			28,249			519,565									Net changes in advances with consolidated entities	286,991			(295,105		)	8,114			—
	Net increase (decrease) in cash and cash equivalents	1,346			(7,302		)	(77		)	(6,033		)							Net cash provided by (used in) financing activities	464,474			(55,220		)	8,462			417,716
	Cash and cash equivalents, beginning of period	—			11,206			355			11,561									Net increase (decrease) in cash and cash equivalents	(41		)	3,612			158			3,729
	Cash and cash equivalents, end of period	$	1,346		$	3,904		$	278		$	5,528								Cash and cash equivalents, beginning of period	41			7,594			197			7,832
																			Cash and cash equivalents, end of period	$	—		$	11,206		$	355		$	11,561
																			NGL ENERGY PARTNERS LP
																			Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
																				Year Ended March 31, 2012
																				NGL Energy
																				Partners LP			Guarantor			Non-Guarantor
																				(Parent)			Subsidiaries			Subsidiaries			Consolidated
																			OPERATING ACTIVITIES:
																			Net cash provided by (used in) operating activities	$	—		$	90,477		$	(148	)	$	90,329
																			INVESTING ACTIVITIES:
																			Purchases of long-lived assets	—			(6,667		)	(877		)	(7,544		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(291,097		)	(6,304		)	—			(297,401		)
																			Cash flows from commodity derivatives	—			6,464			—			6,464
																			Proceeds from sales of assets	—			1,238			—			1,238
																			Other	—			346			—			346
																			Net cash used in investing activities	(291,097		)	(4,923		)	(877		)	(296,897		)
																			FINANCING ACTIVITIES:
																			Proceeds from borrowings under revolving credit facilities	—			478,900			—			478,900
																			Payments on revolving credit facilities	—			(329,900		)	—			(329,900		)
																			Payments on other long-term debt	—			(1,278		)	—			(1,278		)
																			Debt issuance costs	—			(2,380		)	—			(2,380		)
																			Contributions	—			—			440			440
																			Distributions	(19,060		)	—			—			(19,060		)
																			Proceeds from sale of common units, net of offering costs	74,759			—			—			74,759
																			Repurchase of common units	(3,418		)	—			—			(3,418		)
																			Net changes in advances with consolidated entities	238,816			(239,476		)	660			—
																			Net cash provided by (used in) financing activities	291,097			(94,134		)	1,100			198,063
																			Net increase (decrease) in cash and cash equivalents	—			(8,580		)	75			(8,505		)
																			Cash and cash equivalents, beginning of period	41			16,174			122			16,337
																			Cash and cash equivalents, end of period	$	41		$	7,594		$	197		$	7,832

Nature_of_Operations_and_Organ1

Nature of Operations and Organization (Details) (USD $)	0 Months Ended	6 Months Ended		12 Months Ended			0 Months Ended	1 Months Ended
	17-May-11	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Jun. 23, 2014	Jul. 31, 2014
Acquisitions
Equity method ownership interest (as a percent)				50.00%
Initial Public Offering
Proceeds from sale of common units, net of offering costs		$370,446,000	$415,089,000	$650,155,000	($642,000)	$74,759,000
General partner interest (as a percent)	0.10%	0.10%		0.10%	0.10%
Common Units
Initial Public Offering
Number of units sold in public offering	4,025,000						8,000,000
Price per unit of units sold in initial public offering (in dollars per share)	21
Proceeds from sale of common units, net of offering costs							338,000,000	32,400,000
Offering costs							500,000
Number of units redeemed	175,000
Units outstanding after completion of IPO	8,864,222	88,545,764		73,421,309	47,703,313
Common Units | Repayment of advances under acquisition credit facility
Initial Public Offering
Number of units sold in public offering	3,850,000
Proceeds from sale of common units, net of offering costs	71,900,000
Offering costs	9,000,000
Common Units | Redemption of common units
Initial Public Offering
Number of units sold in public offering	175,000
Proceeds from sale of common units, net of offering costs	3,400,000
Subordinated Units
Initial Public Offering
Units outstanding after completion of IPO	5,919,346			5,919,346	5,919,346
Retail propane and distillate operations
Acquisitions
Number of owned terminals		22		22
Retail propane and distillate operations | Minimum
Acquisitions
Number of states in which entity operates		20		20

Nature_of_Operations_and_Organ2

Nature of Operations and Organization (Details 2)	1 Months Ended
	Jan. 31, 2012	Aug. 31, 2013	Mar. 31, 2014	Nov. 01, 2011	Jul. 31, 2013	Dec. 02, 2013	Dec. 31, 2013
	item	item		item	item
Acquisitions Subsequent to Initial Public Offering
Equity method ownership interest (as a percent)			50.00%
SemStream
Acquisitions Subsequent to Initial Public Offering
Number of acquired natural gas liquids terminals				12
Pacer
Acquisitions Subsequent to Initial Public Offering
Number of companies associated with the acquiree entity	7
Crescent Terminals, LLC
Acquisitions Subsequent to Initial Public Offering
Number of tow boats acquired					4
Number of crude oil barges acquired					7
Big Lake
Acquisitions Subsequent to Initial Public Offering
Number of water disposal facilities acquired			1
Oilfield Water Lines LP
Acquisitions Subsequent to Initial Public Offering
Number of companies associated with the acquiree entity		7
Coastal
Acquisitions Subsequent to Initial Public Offering
Number of water disposal facilities acquired			1
Gavilon Energy
Acquisitions Subsequent to Initial Public Offering
Equity method ownership interest (as a percent)						11.00%
Gavilon Energy | Glass Mountain
Acquisitions Subsequent to Initial Public Offering
Equity method ownership interest (as a percent)						50.00%	50.00%

Significant_Accounting_Policie3

Significant Accounting Policies (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Amortization related to intangible assets
Amortization of contract-based intangible assets	$25,812	$13,338	$50,754	$24,636	$72,754	$44,086	$6,615
Cost of sales - wholesale supply and marketing
Amortization related to intangible assets
Amortization of contract-based intangible assets	1,984	949	4,121	1,574	6,172	5,285	800
Cost of sales - wholesale supply and marketing | Contract-based intangibles
Amortization related to intangible assets
Amortization of contract-based intangible assets					$6,200	$5,300	$800

Significant_Accounting_Policie4

Significant Accounting Policies (Details 2) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Supplemental cash flow information
Interest paid, exclusive of debt issuance costs and letter of credit fees	$10,445	$8,423	$36,429	$16,908	$31,827	$27,384	$4,966
Income taxes paid	1,241	369	2,246	650	1,639	1,027	430
Accounts receivable
Allowance for Doubtful Accounts	2,816		2,816		2,822	1,760
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period			2,822	1,760	1,760
Provision for doubtful accounts			1,347	781	2,172	1,315	1,049
Allowance for doubtful accounts, end of period	2,816		2,816		2,822	1,760
Accounts Receivable - Trade:
Accounts receivable
Gross Receivable					903,726	564,517
Allowance for Doubtful Accounts					2,822	1,760	818
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, beginning of period				1,760	1,760	818	161
Provision for doubtful accounts					2,172	1,315	1,049
Write off of uncollectible accounts					-1,110	-373	-392
Allowance for doubtful accounts, end of period					2,822	1,760	818
Accounts Receivable - Trade: | Crude oil logistics
Accounts receivable
Gross Receivable					411,090	360,589
Allowance for Doubtful Accounts					105	11
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, end of period					105	11
Accounts Receivable - Trade: | Water solutions
Accounts receivable
Gross Receivable					25,700	9,618
Allowance for Doubtful Accounts					405	29
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, end of period					405	29
Accounts Receivable - Trade: | Liquids
Accounts receivable
Gross Receivable					192,529	144,267
Allowance for Doubtful Accounts					617	76
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, end of period					617	76
Accounts Receivable - Trade: | Retail propane
Accounts receivable
Gross Receivable					75,606	49,233
Allowance for Doubtful Accounts					1,667	1,644
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, end of period					1,667	1,644
Accounts Receivable - Trade: | Refined products
Accounts receivable
Gross Receivable					105,670
Accounts Receivable - Trade: | Renewables
Accounts receivable
Gross Receivable					54,466
Accounts Receivable - Trade: | Other
Accounts receivable
Gross Receivable					38,665	810
Allowance for Doubtful Accounts					28
Changes in the allowance for doubtful accounts
Allowance for doubtful accounts, end of period					$28

Significant_Accounting_Policie5

Significant Accounting Policies (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Sep. 30, 2014
Inventories
Crude oil	156,473	46,156	$136,722
Natural gas liquids:
Propane	85,159	45,428	207,694
Butane and other	19,051	24,090
Refined products	23,209
Renewables	11,778		36,517
Other	14,490	11,221
Inventories	310,160	126,895	$941,589
Consolidated total revenues | Customer concentration risk | Crude oil and natural gas liquids | Largest customer
Concentration of Credit Risk
Percentage of concentration risk	10.00%	10.00%
Consolidated accounts receivable | Customer concentration risk | Crude oil logistics
Concentration of Credit Risk
Number of customers or suppliers		1
Percentage of concentration risk		10.00%

Significant_Accounting_Policie6

Significant Accounting Policies (Details 4) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Dec. 02, 2013	Dec. 31, 2013
In Thousands, unless otherwise specified
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)		50.00%
Accrued Expenses and Other Payables
Accrued compensation and benefits	$49,146	$45,006	$27,252
Derivative liabilities	39,023	42,214	12,701
Income and other tax liabilities	38,255	13,421	22,659
Product exchange liabilities	43,185	3,719	6,741
Other		37,330	16,253
Total accrued expenses and other payables	$218,482	$141,690	$85,606
Gavilon Energy
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)				11.00%
Gavilon Energy | Glass Mountain
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)				50.00%	50.00%
Gavilon Energy | Limited liability company
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)				11.00%	11.00%

Significant_Accounting_Policie7

Significant Accounting Policies (Details 5) (Water facility development agreement)	12 Months Ended
	Mar. 31, 2014
	item
Water facility development agreement
Water facility development agreement
Maximum period for which the option is available to operate the facility	90 days
Number of options specified in the agreement for the calculation of the purchase price	2

Earnings_per_Unit_Details

Earnings per Unit (Details) (USD $)	3 Months Ended										6 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Earnings per unit
Net loss attributable to parent equity	-19,224		42,331	23,898	($941)	-17,633	22,341	40,176	10,073	-24,650	($59,199)	($18,574)	$47,655	$47,940	$7,876
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056				-2,451						-20,437	-4,139	-14,148	-2,917	-8
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280				-3,392						-79,636	-22,713	33,507	45,023	7,868
Common unitholders
Earnings per unit
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280				-2,830						-75,623	-19,637	31,614	39,517	4,859
Weighted average units outstanding (in shares)	88,331,653		73,421,309	67,941,726	58,909,389	47,703,313	47,665,015	46,364,381	44,831,836	26,529,133	81,267,742	53,336,969	61,970,471	41,353,574	15,169,983
Basic and diluted income (loss) per unit (in dollars per share)	-0.34				($0.05)						($0.93)	($0.37)	$0.51	$0.96	$0.32
Subordinated unitholders
Earnings per unit
NET LOSS ALLOCATED TO LIMITED PARTNERS					$562						$4,013	$3,076	$1,893	$5,506	$3,009
Weighted average units outstanding (in shares)	5,919,346		5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346		5,919,346	5,919,346	5,919,346	5,175,384
Basic and diluted income (loss) per unit (in dollars per share)		($0.68)			($0.09)							($0.52)	$0.32	$0.93	$0.58

Acquisitions_Details

Acquisitions (Details) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended			0 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Dec. 02, 2013	Mar. 31, 2011	Jun. 19, 2012
Acquisitions
Cash paid, net of cash acquired													$14,000,000
Equity method ownership interest (as a percent)		50.00%										50.00%
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	1,170,490,000	1,107,006,000				555,220,000				1,170,490,000		1,107,006,000	555,220,000	167,245,000		8,568,000
REVENUES	5,380,526,000	3,975,935,000	2,743,445,000	1,593,937,000	1,385,957,000	1,617,613,000	1,338,208,000	1,135,510,000	326,436,000	9,029,140,000	2,979,894,000	9,699,274,000	4,417,767,000	1,310,473,000
Operating income	7,770,000			9,945,000						-12,785,000	2,603,000	106,565,000	87,307,000	15,030,000
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment																	17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										2 years		2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment												3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment												25 years
Information technology equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Information technology equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										7 years		7 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Gavilon Energy
Acquisitions
Cash paid, net of cash acquired															832,400,000
General and administrative expense		5,300,000										5,300,000
Equity method ownership interest (as a percent)															11.00%
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	326,484,000	349,529,000								326,484,000		349,529,000
Accounts receivable - affiliates	2,564,000	2,564,000								2,564,000		2,564,000
Inventories	107,430,000	107,430,000								107,430,000		107,430,000
Prepaid expenses and other current assets	68,322,000	68,322,000								68,322,000		68,322,000
Goodwill	342,769,000	359,169,000								342,769,000		359,169,000
Investments in unconsolidated entities	183,000,000	178,000,000								183,000,000		178,000,000
Other noncurrent assets	2,287,000	9,918,000								2,287,000		9,918,000
Accounts payable - trade	-342,792,000	-342,792,000								-342,792,000		-342,792,000
Accounts payable - affiliates	-2,585,000	-2,585,000								-2,585,000		-2,585,000
Accrued expenses and other payables	-49,447,000	-70,999,000								-49,447,000		-70,999,000
Advance payments received from customers	-10,667,000	-10,667,000								-10,667,000		-10,667,000
Other noncurrent liabilities	-46,056,000	-44,740,000								-46,056,000		-44,740,000
Fair value of net assets acquired	832,448,000	832,448,000								832,448,000		832,448,000
Excess of estimated fair value of investments in unconsolidated subsidiaries		70,000,000										70,000,000
Bonus expense recorded during the period										5,200,000
Additional bonus expense expected										1,600,000
REVENUES												2,900,000,000
Operating income												11,000,000
Gavilon Energy | Employee severance
Estimated fair values of the assets acquired and liabilities assumed
Employee severance expense												3,200,000
Bonus expense recorded during the period												5,000,000
Additional bonus expense expected												6,600,000
Gavilon Energy | Crude oil storage lease commitments
Estimated fair values of the assets acquired and liabilities assumed
Liability recorded in the acquisition accounting	15,900,000	12,900,000								15,900,000		12,900,000			13,900,000
Amortization of contract liabilities through cost of sales										5,000,000		2,900,000
Future amortization
2015												6,500,000
2016										4,040,000		3,260,000
2017										360,000		300,000
Gavilon Energy | Storage and transportation contracts of natural gas
Estimated fair values of the assets acquired and liabilities assumed
Liability recorded in the acquisition accounting		50,800,000										50,800,000
Amortization of contract liabilities through cost of sales												6,000,000
Future amortization
Payments for assignment of contracts												44,800,000
Gavilon Energy | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	107,950,000	101,600,000								107,950,000		101,600,000
Gavilon Energy | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										10 years		10 years
Gavilon Energy | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										20 years		20 years
Gavilon Energy | Lease contracts
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	8,700,000	8,700,000								8,700,000		8,700,000
Gavilon Energy | Lease contracts | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										1 year		1 year
Gavilon Energy | Lease contracts | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										5 years		5 years
Gavilon Energy | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	83,797,000	77,429,000								83,797,000		77,429,000
Gavilon Energy | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Gavilon Energy | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Gavilon Energy | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	327,000	791,000								327,000		791,000
Useful life of property, plant and equipment										3 years		3 years
Gavilon Energy | Information technology equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	4,049,000	4,046,000								4,049,000		4,046,000
Gavilon Energy | Information technology equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Gavilon Energy | Information technology equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										7 years		7 years
Gavilon Energy | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	7,817,000	7,716,000								7,817,000		7,716,000
Gavilon Energy | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Gavilon Energy | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Gavilon Energy | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	6,427,000	6,427,000								6,427,000		6,427,000
Gavilon Energy | Linefill and tank bottoms
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		15,230,000										15,230,000
Goodwill															29,000,000
Gavilon Energy | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	162,000	170,000								162,000		170,000
Useful life of property, plant and equipment										7 years		7 years
Gavilon Energy | Construction in process
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	7,180,000	7,190,000								7,180,000		7,190,000
Goodwill															$29,000,000
Gavilon Energy | Glass Mountain
Acquisitions
Equity method ownership interest (as a percent)			50.00%												50.00%

Acquisitions_Details_2

Acquisitions (Details 2) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended			0 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Aug. 02, 2013	Mar. 31, 2011
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$1,170,490,000	$1,107,006,000				$555,220,000				$1,170,490,000		$1,107,006,000	$555,220,000	$167,245,000		$8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired													14,000,000
REVENUES	5,380,526,000	3,975,935,000	2,743,445,000	1,593,937,000	1,385,957,000	1,617,613,000	1,338,208,000	1,135,510,000	326,436,000	9,029,140,000	2,979,894,000	9,699,274,000	4,417,767,000	1,310,473,000
Operating income	7,770,000			9,945,000						-12,785,000	2,603,000	106,565,000	87,307,000	15,030,000
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										30 years		30 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment												3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment												25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Oilfield Water Lines LP
Acquisitions
Number of common units issued to acquire business (in shares)												2,463,287			2,463,287
Period of performance targets as basis for contingent consideration												6 months
Potential increase in the purchase price		0										0
General and administrative expense		800,000										800,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	6,837,000	7,268,000								6,837,000		7,268,000
Inventories	154,000	154,000								154,000		154,000
Prepaid expenses and other current assets	402,000	402,000								402,000		402,000
Goodwill	90,144,000	89,699,000								90,144,000		89,699,000
Accounts payable - trade	-6,469,000	-6,469,000								-6,469,000		-6,469,000
Accrued expenses and other payables	-992,000	-992,000								-992,000		-992,000
Other noncurrent liabilities	-64,000	-64,000								-64,000		-64,000
Fair value of net assets acquired	236,289,000	236,289,000								236,289,000		236,289,000
Consideration paid for acquisition
Cash paid, net of cash acquired												167,732,000			167,700,000
Value of common units issued												68,557,000			68,600,000
Total consideration paid												236,289,000
REVENUES												26,200,000
Operating income												900,000
Oilfield Water Lines LP | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	110,000,000	110,000,000								110,000,000		110,000,000
Useful life of intangible assets												10 years
Oilfield Water Lines LP | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										8 years
Oilfield Water Lines LP | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets										10 years
Oilfield Water Lines LP | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	2,000,000	2,000,000								2,000,000		2,000,000
Useful life of intangible assets										3 years		2 years 6 months
Oilfield Water Lines LP | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	710,000	710,000								710,000		710,000
Oilfield Water Lines LP | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	23,173,000	23,173,000								23,173,000		23,173,000
Oilfield Water Lines LP | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Oilfield Water Lines LP | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										30 years		30 years
Oilfield Water Lines LP | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	8,143,000	8,157,000								8,143,000		8,157,000
Oilfield Water Lines LP | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										5 years		5 years
Oilfield Water Lines LP | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										10 years		10 years
Oilfield Water Lines LP | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	2,198,000	2,198,000								2,198,000		2,198,000
Oilfield Water Lines LP | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										7 years		7 years
Oilfield Water Lines LP | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										30 years		30 years
Oilfield Water Lines LP | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	$53,000	$53,000								$53,000		$53,000
Oilfield Water Lines LP | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Oilfield Water Lines LP | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										5 years		5 years

Acquisitions_Details_3

Acquisitions (Details 3) (USD $)

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

Sep. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Mar. 02, 2014

Mar. 31, 2011

item

item

Acquisitions

Number of business acquired

2

REVENUES

$5,380,526,000

$3,975,935,000

$2,743,445,000

$1,593,937,000

$1,385,957,000

$1,617,613,000

$1,338,208,000

$1,135,510,000

$326,436,000

$9,029,140,000

$2,979,894,000

$9,699,274,000

$4,417,767,000

$1,310,473,000

Operating income

7,770,000

9,945,000

-12,785,000

2,603,000

106,565,000

87,307,000

15,030,000

Estimated fair values of the assets acquired and liabilities assumed

Goodwill

1,170,490,000

1,107,006,000

555,220,000

1,170,490,000

1,107,006,000

555,220,000

167,245,000

8,568,000

Consideration paid for acquisition

Cash paid, net of cash acquired

14,000,000

Water facility development agreement

Consideration paid for acquisition

Number of options specified in the agreement for the calculation of the purchase price

2

Maximum period for which the option is available to operate the facility

90 days

Vehicles | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

3 years

Vehicles | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

25 years

Water treatment facilities and equipment | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

3 years

3 years

Water treatment facilities and equipment | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

30 years

30 years

Buildings and leasehold improvements | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

3 years

3 years

Buildings and leasehold improvements | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

40 years

40 years

Other Water Services

Acquisitions

Number of business acquired

4

Number of common units issued to acquire business (in shares)

222,381

General and administrative expense

400,000

400,000

REVENUES

20,600,000

Operating income

7,100,000

Estimated fair values of the assets acquired and liabilities assumed

Accounts receivable - trade

2,391,000

2,391,000

Inventories

390,000

390,000

Prepaid expenses and other current assets

61,000

61,000

Goodwill

63,031,000

63,031,000

Accounts payable - trade

-382,000

-382,000

Accrued expenses and other payables

-300,000

-300,000

Other noncurrent liabilities

-114,000

-114,000

Fair value of net assets acquired

185,653,000

185,653,000

Consideration paid for acquisition

Cash paid, net of cash acquired

178,867,000

Value of common units issued

6,786,000

Total consideration paid

185,653,000

Other Water Services | Customer relationships

Estimated fair values of the assets acquired and liabilities assumed

Intangible assets

72,000,000

72,000,000

Other Water Services | Trade names

Estimated fair values of the assets acquired and liabilities assumed

Intangible assets

3,325,000

3,325,000

Other Water Services | Non-compete agreements

Estimated fair values of the assets acquired and liabilities assumed

Intangible assets

260,000

260,000

Useful life of intangible assets

3 years

Other Water Services | Water facility development agreement

Estimated fair values of the assets acquired and liabilities assumed

Intangible assets

14,000,000

14,000,000

Useful life of intangible assets

5 years

Other Water Services | Water facility option agreement

Estimated fair values of the assets acquired and liabilities assumed

Intangible assets

2,500,000

2,500,000

Other Water Services | Water facility development agreement

Consideration paid for acquisition

Total consideration paid

21,000,000

Number of options specified in the agreement for the calculation of the purchase price

3

Maximum period for which the option is available to operate the facility

90 days

Other Water Services | Minimum | Customer relationships

Estimated fair values of the assets acquired and liabilities assumed

Useful life of intangible assets

8 years

Other Water Services | Maximum | Customer relationships

Estimated fair values of the assets acquired and liabilities assumed

Useful life of intangible assets

10 years

Other Water Services | Land

Estimated fair values of the assets acquired and liabilities assumed

Property, plant and equipment

419,000

419,000

Other Water Services | Vehicles

Estimated fair values of the assets acquired and liabilities assumed

Property, plant and equipment

90,000

90,000

Other Water Services | Vehicles | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

5 years

Other Water Services | Vehicles | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

10 years

Other Water Services | Water treatment facilities and equipment

Estimated fair values of the assets acquired and liabilities assumed

Property, plant and equipment

24,933,000

24,933,000

Other Water Services | Water treatment facilities and equipment | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

3 years

Other Water Services | Water treatment facilities and equipment | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

30 years

Other Water Services | Buildings and leasehold improvements

Estimated fair values of the assets acquired and liabilities assumed

Property, plant and equipment

3,036,000

3,036,000

Other Water Services | Buildings and leasehold improvements | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

7 years

Other Water Services | Buildings and leasehold improvements | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

30 years

Other Water Services | Other

Estimated fair values of the assets acquired and liabilities assumed

Property, plant and equipment

13,000

13,000

Other Water Services | Other | Minimum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

3 years

Other Water Services | Other | Maximum

Estimated fair values of the assets acquired and liabilities assumed

Useful life of property, plant and equipment

5 years

Saltwater disposal facility

Consideration paid for acquisition

Cash paid, net of cash acquired

$3,700,000

Acquisitions_Details_4

Acquisitions (Details 4) (USD $)	12 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012
	item
Acquisitions
Number of business combination agreements	2
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$555,220,000	1,107,006,000	1,170,490,000	$167,245,000	$8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000,000
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude Oil Logistics
Acquisitions
Number of business combination agreements		2
Common units issued		175,211
General and administrative expense		100,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		1,235,000	1,221,000
Inventories		1,021,000	1,021,000
Prepaid expenses and other current assets		54,000	58,000
Goodwill		37,867,000	30,730,000
Accounts payable - trade		-665,000	-521,000
Accrued expenses and other payables		-124,000	-266,000
Fair value of net assets acquired		73,090,000	73,090,000
Consideration paid for acquisition
Cash paid, net of cash acquired		67,800,000
Value of common units issued		5,300,000
Total consideration paid		73,090,000
Crude Oil Logistics | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		6,300,000	13,300,000
Useful life of intangible assets		3 years	3 years
Crude Oil Logistics | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		530,000	530,000
Crude Oil Logistics | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		35,000	35,000
Useful life of intangible assets		3 years	3 years
Crude Oil Logistics | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,977,000	2,980,000
Crude Oil Logistics | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Crude Oil Logistics | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		10 years	10 years
Crude Oil Logistics | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		280,000	58,000
Crude Oil Logistics | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Crude Oil Logistics | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Crude Oil Logistics | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		3,462,000	3,822,000
Crude Oil Logistics | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude Oil Logistics | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Crude Oil Logistics | Barges and towboats
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		20,065,000	20,065,000
Useful life of property, plant and equipment		20 years	20 years
Crude Oil Logistics | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		53,000	57,000
Crude Oil Logistics | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Crude Oil Logistics | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years

Acquisitions_Details_5

Acquisitions (Details 5) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014
	item	item	item
Acquisitions
Number of business combination agreements	2
Cash paid	$14,000
Retail propane
Acquisitions
Number of business combination agreements		3	4
Cash paid		6,400
Retail propane and liquids
Acquisitions
Cash paid			21,900
Natural gas liquids terminals
Acquisitions
Number of business combination agreements			4

Acquisitions_Details_6

Acquisitions (Details 6) (USD $)	12 Months Ended	0 Months Ended	12 Months Ended	6 Months Ended	1 Months Ended
	Mar. 31, 2013	Jun. 19, 2012	Mar. 31, 2014	Sep. 30, 2014	Jun. 30, 2012	Mar. 31, 2012	Mar. 31, 2011
Acquisitions
Cash paid to acquire ownership interests	$14,000,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220,000		1,107,006,000	1,170,490,000		167,245,000	8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000,000
General partner
Acquisitions
Amount paid		50,000,000
Common units issued		2,685,042
General partner | Common Units
Acquisitions
Common units issued		2,685,042
Value of common units issued		8,000,000
Fair value of common units issued		60,600,000
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			25 years
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			3 years	3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			30 years	30 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			40 years	40 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			40 years	40 years
Information technology equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			3 years	3 years
Information technology equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life			7 years	7 years
High Sierra
Acquisitions
Cash paid to acquire ownership interests		239,251,000
General and administrative expense	3,700,000
Equity issuance costs	600,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		395,311,000
Inventories		43,575,000
Accounts receivable - affiliates		7,724,000
Derivative assets		10,646,000
Forward purchase and sale contracts		34,717,000
Prepaid expenses and other current assets		11,131,000
Goodwill		220,884,000
Assumed liabilities:
Accounts payable - trade		-417,369,000
Accounts payable - affiliates		-9,014,000
Advance payments received from customers		-1,237,000
Accrued expenses and other payables		-35,611,000
Derivative liabilities		-5,726,000
Forward purchase and sale contracts		-18,680,000
Long-term debt		-2,537,000
Other noncurrent liabilities		-3,224,000
Noncontrolling interest in consolidated subsidiary		-2,400,000
Fair value of net assets acquired		654,045,000
Consideration paid for acquisition
Cash paid, net of cash acquired		239,251,000
Total consideration paid		654,045,000
High Sierra | Common Units
Consideration paid for acquisition
Value of common units issued		414,794,000
High Sierra | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		13,000,000
High Sierra | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		245,000,000
High Sierra | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets					5 years
High Sierra | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets					17 years
High Sierra | Lease and other agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		12,400,000
High Sierra | Lease and other agreements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets					1 year
High Sierra | Lease and other agreements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets					10 years
High Sierra | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		5,723,000
High Sierra | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		22,507,000
High Sierra | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					5 years
High Sierra | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					10 years
High Sierra | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		64,057,000
High Sierra | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					3 years
High Sierra | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					30 years
High Sierra | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					2 years
High Sierra | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					15 years
High Sierra | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		19,145,000
High Sierra | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					5 years
High Sierra | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					30 years
High Sierra | Information technology equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		5,541,000
Useful life					3 years
High Sierra | Other equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		11,010,000
High Sierra | Other equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					2 years
High Sierra | Other equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life					30 years
High Sierra | Construction in progress
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		9,621,000
High Sierra Energy, LP
Acquisitions
Cash paid to acquire ownership interests		91,800,000
Cash acquired		5,000,000
Amount of additional consideration payable		97,400,000
Common units issued		18,018,468
Consideration paid for acquisition
Cash paid, net of cash acquired		91,800,000
High Sierra Energy, LP | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)		18,018,468
Value of common units issued using the closing price of units on the New York Stock Exchange on the merger date		406,800,000
High Sierra Energy, LP | General partner
Acquisitions
Cash paid to acquire ownership interests		50,000,000
Consideration paid for acquisition
Cash paid, net of cash acquired		50,000,000
High Sierra Energy GP, LLC | General partner
Acquisitions
Cash paid to acquire ownership interests		50,000,000
Consideration paid for acquisition
Cash paid, net of cash acquired		$50,000,000

Acquisitions_Details_7

Acquisitions (Details 7) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Nov. 01, 2012	Nov. 12, 2012	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$555,220,000	1,170,490,000	1,107,006,000			$167,245,000	$8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000,000
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment								17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Pecos
Acquisitions
Amount of additional consideration payable				10,200,000
General and administrative expense	600,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			73,609,000
Inventories			1,903,000
Prepaid expenses and other current assets			1,426,000
Goodwill			91,747,000
Accounts payable - trade			-50,795,000
Accrued expenses and other payables			-963,000
Long-term debt			-10,234,000
Fair value of net assets acquired			132,387,000
Consideration paid for acquisition
Cash paid, net of cash acquired			87,444,000
Value of common units issued			44,943,000
Total consideration paid			132,387,000
Pecos | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	73,704,000
Inventories	1,903,000
Prepaid expenses and other current assets	1,426,000
Goodwill	86,661,000
Accounts payable - trade	-50,808,000
Accrued expenses and other payables	-1,020,000
Long-term debt	-10,234,000
Fair value of net assets acquired	132,387,000
Pecos | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-95,000
Goodwill			5,086,000
Accounts payable - trade			13,000
Accrued expenses and other payables			57,000
Pecos | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			900,000
Pecos | Trade names | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	1,000,000
Pecos | Trade names | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			-100,000
Pecos | Customer relationships | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	8,000,000
Pecos | Customer relationships | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			-8,000,000
Pecos | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			22,097,000
Pecos | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years
Pecos | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			10 years
Pecos | Vehicles | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	19,193,000
Pecos | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			2,904,000
Pecos | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,339,000
Pecos | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years
Pecos | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			30 years
Pecos | Buildings and leasehold improvements | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,248,000
Pecos | Buildings and leasehold improvements | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			91,000
Pecos | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,099,000
Pecos | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			2 years
Pecos | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			15 years
Pecos | Crude oil tanks and related equipment | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	913,000
Pecos | Crude oil tanks and related equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			186,000
Pecos | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			223,000
Pecos | Land | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	224,000
Pecos | Land | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-1,000
Pecos | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			36,000
Pecos | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Pecos | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years
Pecos | Other | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	177,000
Pecos | Other | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-141,000
Pecos | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)					1,834,414
Consideration paid for acquisition
Value of common units issued					45,000,000
Pecos | Common Units | Minimum
Consideration paid for acquisition
Value of common units issued				45,000,000
Pecos | Common Units | Maximum
Consideration paid for acquisition
Value of common units issued				$60,000,000

Acquisitions_Details_8

Acquisitions (Details 8) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Jan. 11, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2011
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$555,220	1,170,490	1,107,006			$167,245	$8,568
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000
Barges and towboats | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Barges and towboats | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Third Coast
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			2,195
Inventories			140
Goodwill			18,847
Other noncurrent assets			2,733
Accounts payable - trade			-2,429
Accrued expenses and other payables			-164
Fair value of net assets acquired			42,883
Consideration paid for acquisition
Cash paid, net of cash acquired			35,000
Value of common units issued			7,883
Total consideration paid			42,883
Third Coast | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	2,248
Inventories	140
Goodwill	22,551
Other noncurrent assets	2,733
Accounts payable - trade	-2,048
Accrued expenses and other payables	-154
Fair value of net assets acquired	42,883
Third Coast | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-53
Goodwill			-3,704
Accounts payable - trade			-381
Accrued expenses and other payables			-10
Third Coast | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			850
Third Coast | Trade names | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	500
Third Coast | Trade names | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			350
Third Coast | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			3,000
Useful life of intangible assets			3 years
Third Coast | Customer relationships | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	4,000
Third Coast | Customer relationships | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			-1,000
Third Coast | Barges and towboats
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			17,711
Useful life of property, plant and equipment			20 years
Third Coast | Barges and towboats | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	12,883
Third Coast | Barges and towboats | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			4,828
Third Coast | Other | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	30
Third Coast | Other | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-30
Third Coast | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)				344,680
Consideration paid for acquisition
Value of common units issued				8,000
Third Coast | Common Units | Minimum
Consideration paid for acquisition
Value of common units issued					8,000
Third Coast | Common Units | Maximum
Consideration paid for acquisition
Value of common units issued					$10,000

Acquisitions_Details_9

Acquisitions (Details 9) (USD $)	12 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012
	item
Acquisitions
Number of business combination agreements	2
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$555,220,000	1,107,006,000	1,170,490,000	$167,245,000	$8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000,000
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude oil logistics and water solutions
Acquisitions
Number of business combination agreements	4
Liabilities assumed in the form of non-compete agreements	1,300,000
Number of common units issued to acquire business (in shares)		516,978
General and administrative expense	300,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		2,676,000
Inventories		191,000
Prepaid expenses and other current assets		737,000
Goodwill		34,451,000
Accounts payable - trade		-3,374,000
Accrued expenses and other payables		-1,914,000
Notes payable		-1,340,000
Other noncurrent liabilities	-1,340,000	-156,000
Noncontrolling interest		-2,333,000
Fair value of net assets acquired		64,985,000
Consideration paid for acquisition
Cash paid, net of cash acquired		52,552,000
Value of common units issued		12,433,000
Total consideration paid		64,985,000
Crude oil logistics and water solutions | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	2,660,000
Inventories	191,000
Prepaid expenses and other current assets	738,000
Goodwill	43,822,000
Accounts payable - trade	-3,374,000
Accrued expenses and other payables	-2,026,000
Notes payable	-1,340,000
Other noncurrent liabilities	-156,000
Noncontrolling interest	-2,333,000
Fair value of net assets acquired	64,985,000
Crude oil logistics and water solutions | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		16,000
Prepaid expenses and other current assets		-1,000
Goodwill		-9,371,000
Accrued expenses and other payables		112,000
Crude oil logistics and water solutions | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		2,100,000
Crude oil logistics and water solutions | Trade names | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	500,000
Crude oil logistics and water solutions | Trade names | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		1,600,000
Crude oil logistics and water solutions | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		13,125,000
Crude oil logistics and water solutions | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		5 years
Crude oil logistics and water solutions | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		10 years
Crude oil logistics and water solutions | Customer relationships | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	6,800,000
Crude oil logistics and water solutions | Customer relationships | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		6,325,000
Crude oil logistics and water solutions | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		164,000
Useful life of intangible assets		3 years
Crude oil logistics and water solutions | Non-compete agreements | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	510,000
Crude oil logistics and water solutions | Non-compete agreements | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		-346,000
Crude oil logistics and water solutions | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		218,000
Crude oil logistics and water solutions | Land | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	191,000
Crude oil logistics and water solutions | Land | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		27,000
Crude oil logistics and water solutions | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		853,000
Crude oil logistics and water solutions | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years
Crude oil logistics and water solutions | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		10 years
Crude oil logistics and water solutions | Vehicles | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	771,000
Crude oil logistics and water solutions | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		82,000
Crude oil logistics and water solutions | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		13,665,000
Crude oil logistics and water solutions | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Crude oil logistics and water solutions | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years
Crude oil logistics and water solutions | Water treatment facilities and equipment | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	13,322,000
Crude oil logistics and water solutions | Water treatment facilities and equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		343,000
Crude oil logistics and water solutions | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		895,000
Crude oil logistics and water solutions | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years
Crude oil logistics and water solutions | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years
Crude oil logistics and water solutions | Buildings and leasehold improvements | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	2,233,000
Crude oil logistics and water solutions | Buildings and leasehold improvements | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		-1,338,000
Crude oil logistics and water solutions | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		4,510,000
Crude oil logistics and water solutions | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years
Crude oil logistics and water solutions | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		15 years
Crude oil logistics and water solutions | Crude oil tanks and related equipment | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,781,000
Crude oil logistics and water solutions | Crude oil tanks and related equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,729,000
Crude oil logistics and water solutions | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		27,000
Crude oil logistics and water solutions | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Crude oil logistics and water solutions | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years
Crude oil logistics and water solutions | Other | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	2,000
Crude oil logistics and water solutions | Other | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		25,000
Crude oil logistics and water solutions | Construction in progress
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		490,000
Crude oil logistics and water solutions | Construction in progress | Estimated at March 31, 2014
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	693,000
Crude oil logistics and water solutions | Construction in progress | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		-203,000

Acquisitions_Details_10

Acquisitions (Details 10) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2012	Mar. 31, 2011
	item
Acquisitions
Number of business combination agreements	2
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	$555,220,000	1,170,490,000	1,107,006,000	$167,245,000	$8,568,000
Consideration paid for acquisition
Cash paid, net of cash acquired	14,000,000
Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Retail Propane Combinations
Acquisitions
Number of business combination agreements	6
Liabilities assumed in the form of non-compete agreements	6,600,000
General and administrative expense	300,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	8,715,000
Inventory purchased	5,155,000
Other current assets	1,228,000
Goodwill	21,983,000
Other non-current assets	784,000
Long-term debt	-6,594,000
Other assumed liabilities	-12,511,000
Fair value of net assets acquired	90,266,000
Consideration paid for acquisition
Cash paid, net of cash acquired	71,392,000
Total consideration paid	90,266,000
Retail Propane Combinations | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	2,924,000
Retail Propane Combinations | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	16,890,000
Retail Propane Combinations | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets	10 years
Retail Propane Combinations | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets	15 years
Retail Propane Combinations | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	1,387,000
Useful life of intangible assets	5 years
Retail Propane Combinations | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,945,000
Retail Propane Combinations | Retail propane equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	28,763,000
Retail Propane Combinations | Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	5 years
Retail Propane Combinations | Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	20 years
Retail Propane Combinations | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	11,344,000
Useful life of property, plant and equipment	5 years
Retail Propane Combinations | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	7,052,000
Useful life of property, plant and equipment	30 years
Retail Propane Combinations | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,201,000
Retail Propane Combinations | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)	850,676
Consideration paid for acquisition
Value of common units issued	$18,874,000

Acquisitions_Details_11

Acquisitions (Details 11) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
High Sierra, Pecos, Third Coast, OWL and Gavilon Energy acquisitions
Construction in progress
Revenues	$9,800,398	$5,697,988
Net income (loss)	798	-72,171
High Sierra, Pecos, Third Coast, OWL and Gavilon Energy acquisitions | Common Units
Construction in progress
Basic loss per unit (in dollars per share)	($0.18)	($0.95)
Diluted loss per unit (in dollars per share)	($0.18)	($0.95)
High Sierra, Pecos, Third Coast, OWL and Gavilon Energy acquisitions | Subordinated Units
Construction in progress
Basic loss per unit (in dollars per share)	($0.18)	($0.95)
Diluted loss per unit (in dollars per share)	($0.18)	($0.95)
High Sierra, Pecos, Third Coast, OWL and Gavilon Energy acquisitions | Limited Partners
Construction in progress
Net income (loss)	-14,446	-75,251
OWL
Construction in progress
Expense related to retirement of liability		$4,800

Acquisitions_Details_12

Acquisitions (Details 12) (USD $)	6 Months Ended		12 Months Ended			0 Months Ended	1 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Oct. 03, 2011	Nov. 30, 2012	Mar. 31, 2011
Acquisitions
Cash paid to acquire ownership interests, net of cash acquired	$658,764,000	$392,605,000	$1,268,810,000	$490,805,000	$297,401,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	1,170,490,000		1,107,006,000	555,220,000	167,245,000			8,568,000
Consideration paid for acquisition
Cash paid for water facilities				14,000,000
Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	2 years		2 years
Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	30 years		30 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	3 years		3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment	40 years		40 years
Osterman
Acquisitions
Cash paid to acquire ownership interests, net of cash acquired						94,900,000
Working capital items, post-closing payment							4,800,000
General and administrative expense					800,000
Equity issuance costs					100,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade						9,350,000
Inventories						3,869,000
Prepaid expenses and other current assets						215,000
Goodwill						52,267,000
Assumed liabilities						-9,654,000
Fair value of net assets acquired						181,516,000
Consideration paid for acquisition
Cash paid for water facilities						94,873,000
Value of common units issued to acquire ownership interests						81,880,000
Working capital payment (paid in November 2012)						4,763,000
Total consideration paid						181,516,000
Osterman | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets						8,500,000
Osterman | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets						54,500,000
Useful life of intangible assets						20 years
Osterman | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets						700,000
Useful life of intangible assets						7 years
Osterman | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						2,349,000
Osterman | Retail propane equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						47,160,000
Osterman | Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						15 years
Osterman | Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						20 years
Osterman | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						7,699,000
Osterman | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						5 years
Osterman | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						20 years
Osterman | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						3,829,000
Useful life of property, plant and equipment						30 years
Osterman | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						$732,000
Osterman | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						3 years
Osterman | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment						5 years
Osterman | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)					4,000,000	4,000,000
Price per unit of units sold in initial public offering (in dollars per share)						$20.47

Acquisitions_Details_13

Acquisitions (Details 13) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Nov. 01, 2011	Mar. 31, 2012	Mar. 31, 2011
				item
				bbl
				gal
Acquisitions
Cash paid for water facilities	$14,000,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220,000	1,170,490,000	1,107,006,000		167,245,000	8,568,000
Natural gas liquids terminal assets | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Natural gas liquids terminal assets | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Vehicles and railcars | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles and railcars | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
NGL Energy Holdings, LLC | SemStream
Acquisitions
Ownership interest acquired in general partner (as a percent)				7.50%
SemStream
Acquisitions
Cash paid for water facilities				91,000,000
General and administrative expense					700,000
Number of acquired natural gas liquids terminals				12
Volume of acquired above ground propane storage (in gallons)				12,000,000
Volume of acquired underground leased storage (in barrels)				3,700,000
Number of owned rail cars				350
Number of leased rail cars				12
Estimated fair values of the assets acquired and liabilities assumed
Inventories				104,226,000
Derivative assets				3,578,000
Assets held for sale				3,000,000
Prepaid expenses and other current assets				9,833,000
Investment in capital lease				3,112,000
Goodwill				74,924,000
Assumed current liabilities				-4,591,000
Fair value of net assets acquired				275,740,000
SemStream | Maximum
Acquisitions
Equity issuance costs					100,000
SemStream | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Amortizable intangible assets				31,950,000
SemStream | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets				8 years
SemStream | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets				15 years
SemStream | Lease contracts
Estimated fair values of the assets acquired and liabilities assumed
Amortizable intangible assets				1,008,000
SemStream | Lease contracts | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets				1 year
SemStream | Lease contracts | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets				4 years
SemStream | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				3,470,000
SemStream | Natural gas liquids terminal assets
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				41,434,000
SemStream | Natural gas liquids terminal assets | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				20 years
SemStream | Natural gas liquids terminal assets | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				30 years
SemStream | Vehicles and railcars
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				470,000
Useful life of property, plant and equipment				5 years
SemStream | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				3,326,000
Useful life of property, plant and equipment				5 years
SemStream | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)				8,932,031
Value of common units issued to acquire ownership interests				$184,800,000
Issue price of units (in dollars per unit)				($21.07)

Acquisitions_Details_14

Acquisitions (Details 14) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Jan. 03, 2012	Mar. 31, 2012	Mar. 31, 2011
				item
Acquisitions
Cash paid for water facilities	$14,000,000
Consideration paid for acquisition
Cash paid	14,000,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220,000	1,170,490,000	1,107,006,000		167,245,000	8,568,000
Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Pacer Propane Holdings, L.P.
Acquisitions
Cash paid for water facilities				32,213,000
General and administrative expense					700,000
Equity issuance costs					100,000
Number of owned or leased customer service centers				17
Consideration paid for acquisition
Cash paid				32,213,000
Total consideration paid				62,588,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade				4,389,000
Inventories				965,000
Prepaid expenses and other current assets				43,000
Goodwill				15,782,000
Assumed liabilities				-4,399,000
Fair value of net assets acquired				62,588,000
Pacer Propane Holdings, L.P. | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets				2,410,000
Pacer Propane Holdings, L.P. | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets				23,560,000
Useful life of intangible assets				15 years
Pacer Propane Holdings, L.P. | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets				1,520,000
Pacer Propane Holdings, L.P. | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				1,967,000
Pacer Propane Holdings, L.P. | Retail propane equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				12,793,000
Pacer Propane Holdings, L.P. | Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				15 years
Pacer Propane Holdings, L.P. | Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				20 years
Pacer Propane Holdings, L.P. | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				3,090,000
Useful life of property, plant and equipment				5 years
Pacer Propane Holdings, L.P. | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				409,000
Useful life of property, plant and equipment				30 years
Pacer Propane Holdings, L.P. | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment				59,000
Pacer Propane Holdings, L.P. | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				3 years
Pacer Propane Holdings, L.P. | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment				5 years
Pacer Propane Holdings, L.P. | Common Units
Acquisitions
Number of common units issued to acquire business (in shares)				1,500,000
Consideration paid for acquisition
Common units				$30,375,000

Acquisitions_Details_15

Acquisitions (Details 15) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Feb. 03, 2012	Mar. 31, 2012	Mar. 31, 2011
Acquisitions
Cash paid for water facilities	$14,000,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220,000	1,170,490,000	1,107,006,000		167,245,000	8,568,000
Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Natural gas liquids terminal assets | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Natural gas liquids terminal assets | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
North American
Acquisitions
Cash paid for water facilities				69,800,000
General and administrative expense					1,600,000
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			10,338,000
Inventories			3,437,000
Prepaid expenses and other current assets			282,000
Goodwill			13,978,000
Assumed liabilities			-11,129,000
Fair value of net assets acquired			69,830,000
North American | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			12,600,000
Useful life of intangible assets			10 years
North American | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			2,700,000
Useful life of intangible assets			10 years
North American | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			700,000
Useful life of intangible assets			3 years
North American | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			2,251,000
North American | Retail propane equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			24,790,000
North American | Retail propane equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			15 years
North American | Retail propane equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			20 years
North American | Natural gas liquids terminal assets
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,044,000
North American | Natural gas liquids terminal assets | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			15 years
North American | Natural gas liquids terminal assets | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			20 years
North American | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			5,819,000
North American | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years
North American | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			15 years
North American | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			2,386,000
Useful life of property, plant and equipment			30 years
North American | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			634,000
North American | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
North American | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years

Acquisitions_Details_16

Acquisitions (Details 16) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2013	Mar. 31, 2012
	item	item
Acquisitions
Number of business combination agreements	2
Cash paid for water facilities	$14,000
Three separate acquisitions
Acquisitions
Number of business combination agreements		3
Cash paid for water facilities		6,400
Long-term debt assumed		$600

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Property, Plant and Equipment
Property, plant and equipment, gross	$1,586,370,000		$1,586,370,000		$938,910,000	$576,564,000
Less: Accumulated depreciation	-153,057,000		-153,057,000		-109,564,000	-50,127,000
Net property, plant and equipment	1,433,313,000		1,433,313,000		829,346,000	526,437,000
Depreciation expense	28,400,000	13,700,000	46,900,000	27,200,000	59,900,000	39,200,000	10,600,000
Interest expense capitalized					700,000
Natural gas liquids terminal assets
Property, Plant and Equipment
Property, plant and equipment, gross	127,258,000		127,258,000		75,141,000	63,637,000
Natural gas liquids terminal assets | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Natural gas liquids terminal assets | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Retail propane equipment
Property, Plant and Equipment
Property, plant and equipment, gross	167,825,000		167,825,000		160,758,000	152,802,000
Retail propane equipment | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Retail propane equipment | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Vehicles
Property, Plant and Equipment
Property, plant and equipment, gross					152,676,000	88,173,000
Vehicles | Minimum
Property, Plant and Equipment
Useful life					3 years
Vehicles | Maximum
Property, Plant and Equipment
Useful life					25 years
Water treatment facilities and equipment
Property, Plant and Equipment
Property, plant and equipment, gross	209,644,000		209,644,000		180,985,000	91,944,000
Water treatment facilities and equipment | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Water treatment facilities and equipment | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Crude oil tanks and related equipment
Property, Plant and Equipment
Property, plant and equipment, gross	145,287,000		145,287,000		106,125,000	22,577,000
Crude oil tanks and related equipment | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Crude oil tanks and related equipment | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Barges and towboats
Property, Plant and Equipment
Property, plant and equipment, gross	56,094,000		56,094,000		52,217,000	25,963,000
Barges and towboats | Minimum
Property, Plant and Equipment
Useful life			5 years		5 years
Barges and towboats | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Information technology equipment
Property, Plant and Equipment
Property, plant and equipment, gross	30,519,000		30,519,000		20,768,000	12,169,000
Information technology equipment | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Information technology equipment | Maximum
Property, Plant and Equipment
Useful life			7 years		7 years
Buildings and leasehold improvements
Property, Plant and Equipment
Property, plant and equipment, gross	77,415,000		77,415,000		60,004,000	48,975,000
Buildings and leasehold improvements | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Buildings and leasehold improvements | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Land
Property, Plant and Equipment
Property, plant and equipment, gross	88,350,000		88,350,000		30,241,000	21,815,000
Linefill and tank bottoms
Property, Plant and Equipment
Property, plant and equipment, gross					13,403,000
Other
Property, Plant and Equipment
Property, plant and equipment, gross	16,770,000		16,770,000		6,341,000	16,104,000
Other | Minimum
Property, Plant and Equipment
Useful life			3 years		5 years
Other | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Construction in progress
Property, Plant and Equipment
Property, plant and equipment, gross	$57,319,000		$57,319,000		$80,251,000	$32,405,000

Goodwill_Details

Goodwill (Details) (USD $)	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Goodwill
Goodwill at the beginning of the period	$1,107,006	$555,220	$167,245	$8,568
Acquisitions	86,895	551,786	387,975	158,677
Goodwill at the end of the period	$1,170,490	$1,107,006	$555,220	$167,245

Goodwill_Details_2

Goodwill (Details 2) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011
In Thousands, unless otherwise specified
Goodwill by segment
Goodwill	$1,170,490	$1,107,006	$555,220	$167,245	$8,568
Crude oil logistics
Goodwill by segment
Goodwill	579,845	606,383	246,345
Water solutions
Goodwill by segment
Goodwill	320,106	262,203	109,470
Liquids
Goodwill by segment
Goodwill	91,135	90,135	87,136
Retail propane
Goodwill by segment
Goodwill	114,285	114,285	112,269
Refined products
Goodwill by segment
Goodwill		22,000
Renewables
Goodwill by segment
Goodwill		$12,000

Intangible_Assets_Details

Intangible Assets (Details) (USD $)	12 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Sep. 30, 2014	Mar. 31, 2013
Amortizable
Gross Carrying Amount	$809,064	976,952	$454,157
Accumulated Amortization	116,728	166,484	44,155
Non-Amortizable
Gross carrying amount of intangible assets	831,684	1,004,572	485,587
Trade names
Non-Amortizable
Gross Carrying Amount	22,620	27,620
Customer relationships
Amortizable
Gross Carrying Amount	697,405	761,992	405,160
Accumulated Amortization	83,261	119,439	30,959
Useful Lives	9 years
Customer relationships | Minimum
Amortizable
Useful Lives	3 years	3 years
Customer relationships | Maximum
Amortizable
Useful Lives	20 years	20 years
Water facility development agreement
Amortizable
Gross Carrying Amount	14,000	14,000
Accumulated Amortization	2,100	3,500
Useful Lives	5 years	5 years
Lease and other agreements
Amortizable
Gross Carrying Amount	23,920		15,210
Accumulated Amortization	13,190		7,018
Lease and other agreements | Minimum
Amortizable
Useful Lives	5 years
Lease and other agreements | Maximum
Amortizable
Useful Lives	8 years
Non-compete agreements
Amortizable
Gross Carrying Amount	14,161	14,412	11,509
Accumulated Amortization	6,388	8,302	2,871
Non-compete agreements | Minimum
Amortizable
Useful Lives	2 years	2 years
Non-compete agreements | Maximum
Amortizable
Useful Lives	7 years	7 years
Trade names
Amortizable
Gross Carrying Amount	15,489	14,539	2,784
Accumulated Amortization	3,081	5,197	326
Non-Amortizable
Gross Carrying Amount	22,620		31,430
Trade names | Minimum
Amortizable
Useful Lives	2 years	2 years
Trade names | Maximum
Amortizable
Useful Lives	10 years	10 years
Debt issuance costs
Amortizable
Gross Carrying Amount	44,089	53,289	19,494
Accumulated Amortization	$8,708	12,737	$2,981
Debt issuance costs | Minimum
Amortizable
Useful Lives	5 years	5 years
Debt issuance costs | Maximum
Amortizable
Useful Lives	10 years	10 years

Intangible_Assets_Details_2

Intangible Assets (Details 2) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Amortization related to intangible assets
Amortization expense	$25,812	$13,338	$50,754	$24,636	$72,754	$44,086	$6,615
Future amortization expense of intangible assets
2015					88,970
2016	97,432		97,432		83,449
2017	90,795		90,795		76,826
2018	86,818		86,818		72,857
2019	79,587		79,587		66,826
Thereafter	405,266		405,266		303,408
Total	810,468		810,468		692,336
Depreciation and amortization
Amortization related to intangible assets
Amortization expense	21,711	11,324	42,604	20,600	60,855	29,657	4,538
Cost of sales
Amortization related to intangible assets
Amortization expense	1,984	949	4,121	1,574	6,172	5,285	800
Interest expense
Amortization related to intangible assets
Amortization expense	2,117	1,065	4,029	2,462	5,727	3,375	1,277
Loss on early extinguishment of debt
Amortization related to intangible assets
Amortization expense						$5,769

LongTerm_Obligations_Details

Long-Term Obligations (Details) (USD $)	6 Months Ended	12 Months Ended	0 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Oct. 16, 2013	Mar. 31, 2013	Jun. 19, 2012
Long-Term Debt
Total debt	$2,442,413,000	$1,636,914,000		$749,062,000
Less - current maturities	5,062,000	7,080,000		8,626,000
Long-term debt	2,437,351,000	1,629,834,000		740,436,000
Revolving Credit Facility
Long-Term Debt
Outstanding cash borrowings	1,100,000,000	922,000,000
Actual leverage ratio	3.4	3
Actual interest coverage ratio	4.8	7
Interest rate (as a percent)	1.91%	1.98%
Revolving Credit Facility | Minimum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.38%	0.38%
Interest coverage ratio	2.75	2.75
Revolving Credit Facility | Maximum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.50%	0.50%
Leverage ratio	4.25	4.25
Revolving Credit Facility | Alternate base rate
Long-Term Debt
Variable interest rate base	base rate	base rate
Revolving Credit Facility | Alternate base rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	0.50%	0.50%
Revolving Credit Facility | Alternate base rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	1.50%	1.50%
Revolving Credit Facility | LIBOR rate
Long-Term Debt
Variable interest rate base	LIBOR	LIBOR
Interest rate margin added to variable rate base (as a percent)	1.75%	0.16%
Reference rate (as a percent)	0.16%	1.75%
Fixed interest rate (as a percent)	1.91%
Interest rate (as a percent)		1.91%
Revolving Credit Facility | LIBOR rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	1.50%	1.50%
Revolving Credit Facility | LIBOR rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	2.50%	2.50%
Revolving Credit Facility | Expansion Capital Facility
Long-Term Debt
Total debt	137,000,000	532,500,000		441,500,000
Maximum borrowing capacity	858,000,000	785,500,000
Outstanding cash borrowings	137,000,000	532,500,000
Revolving Credit Facility | Expansion Capital Facility | LIBOR rate
Long-Term Debt
Outstanding cash borrowings	137,000,000	532,500,000
Interest rate (as a percent)	0.00%	1.91%
Revolving Credit Facility | Working Capital Facility
Long-Term Debt
Total debt	942,500,000	389,500,000		36,000,000
Maximum borrowing capacity	1,335,000,000	935,500,000
Outstanding cash borrowings	942,500,000	389,500,000
Outstanding letters of credit	209,200,000	270,600,000
Revolving Credit Facility | Working Capital Facility | Alternate base rate
Long-Term Debt
Outstanding cash borrowings		31,500,000
Interest rate (as a percent)		4.00%
Revolving Credit Facility | Working Capital Facility | LIBOR rate
Long-Term Debt
Outstanding cash borrowings	942,500,000	358,000,000
Interest rate (as a percent)	0.00%	1.91%
Revolving Credit Facility | Letters of credit
Long-Term Debt
Reference rate (as a percent)		1.75%
Fixed interest rate (as a percent)	2.00%
6.650% Notes due 2022
Long-Term Debt
Total debt	250,000,000	250,000,000		250,000,000
Fixed interest rate (as a percent)	6.65%	6.65%			6.65%
Debt issued					250,000,000
Repayments in semi-annual installments	25,000,000	25,000,000
6.650% Notes due 2022 | Minimum
Long-Term Debt
Debt covenant terms, default trigger amount	10,000,000	10,000,000
Percentage of aggregate principal amount held by trustee or holders to declare notes due and payable	51.00%	51.00%
Unsecured Notes
Long-Term Debt
Total debt		450,000,000
Fixed interest rate (as a percent)			6.88%
Debt issued			450,000,000
Net proceeds after underwriting fees and estimated offering costs			438,400,000
Initial purchase discount			10,100,000
Estimated offering costs			1,500,000
Other notes payable
Long-Term Debt
Total debt		$14,914,000		$21,562,000
Other notes payable | Minimum
Long-Term Debt
Interest rate (as a percent)		2.10%
Other notes payable | Maximum
Long-Term Debt
Interest rate (as a percent)		4.90%

LongTerm_Obligations_Details_2

Long-Term Obligations (Details 2) (USD $)	0 Months Ended
	Jun. 19, 2012	Sep. 30, 2014	Mar. 31, 2014
Maturities
2015			$7,081,000
2016		255,128,000	3,614,000
2017		2,362,000	2,356,000
2018		26,459,000	26,449,000
2019		1,130,938,000	972,238,000
Thereafter		1,025,181,000	625,176,000
Total long-term debt		2,442,413,000	1,636,914,000
Revolving Credit Facility
Maturities
2019		1,079,500,000	922,000,000
Total long-term debt		1,079,500,000	922,000,000
6.650% Notes due 2022
Maturities
2018		25,000,000	25,000,000
2019		50,000,000	50,000,000
Thereafter		175,000,000	175,000,000
Total long-term debt		250,000,000	250,000,000
Unsecured Notes
Maturities
Thereafter			450,000,000
Total long-term debt			450,000,000
Other Notes Payable
Maturities
2015			7,081,000
2016			3,614,000
2017			2,356,000
2018			1,449,000
2019			238,000
Thereafter			176,000
Total long-term debt			14,914,000
Previous revolving credit facility
Maturities
Principal payment	$306,800,000

Income_Taxes_Details

Income Taxes (Details)	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Income Taxes
Minimum percentage of qualifying income of non-taxable subsidiaries	90.00%	90.00%

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended	1 Months Ended		4 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Aug. 31, 2013	30-May-13	Feb. 28, 2013	Sep. 30, 2014
Legal contingencies
Amount of fuel taxes and sales taxes that should have been collected from customers and remitted to taxing authority	$0.80
Asset retirement obligations
Asset retirement obligations	2.3				2.7
Pecos
Legal contingencies
Amount not paid by customer for disputed transportation rate schedule				1.7
Amount requested as refund by the customer			5.5
Payment intended to withheld by the customer		$3.30

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 2) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Future minimum lease payments
2015					$133,170,000
2016	106,384,000		106,384,000		93,454,000
2017	88,666,000		88,666,000		64,209,000
2018	74,265,000		74,265,000		49,802,000
2019	49,907,000		49,907,000		29,213,000
Thereafter	117,125,000		117,125,000		58,182,000
Total	507,354,000		507,354,000		428,030,000
Rental expense	29,300,000	23,600,000	54,600,000	45,500,000	98,300,000	84,200,000	5,200,000
Prepaid expenses and other current assets
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	44,400,000		44,400,000		43,500,000
Accrued expenses and other payables
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	36,300,000		36,300,000		34,600,000
Natural gas liquids
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price purchase commitments (in gallons)	88,574,000		88,574,000		31,111,000
Floating-price purchase commitments (in gallons)					522,947,000
Fixed-price sale commitments (in gallons)	278,391,000		278,391,000		63,944,000
Floating-price sale commitments (in gallons)					272,495,000
Fixed-price purchase commitments	102,000,000		102,000,000		39,117,000
Floating-price purchase commitments					618,293,000
Fixed-price sale commitments	351,137,000		351,137,000		77,682,000
Floating-price sale commitments					395,095,000
Crude oil
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price sale commitments (in gallons)	32,000		32,000
Fixed-price purchase commitments (in barrels)					4,016,000
Fixed-price sale commitments (in barrels)					3,564,000
Fixed-price purchase commitments					364,557,000
Fixed-price sale commitments	$2,867,000		$2,867,000		$324,765,000

Equity_Details

Equity (Details) (USD $)	0 Months Ended	6 Months Ended		12 Months Ended			0 Months Ended	1 Months Ended
	17-May-11	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Jun. 23, 2014	Jul. 31, 2014
Partnership equity
General partner, interest (as a percent)	0.10%	0.10%		0.10%	0.10%
Limited partners, interest (as a percent)		99.90%		99.90%	99.90%
Initial Public Offering
Proceeds from sale of common units, net of offering costs		$370,446,000	$415,089,000	$650,155,000	($642,000)	$74,759,000
Common Units
Initial Public Offering
Number of units sold in public offering	4,025,000						8,000,000
Price per unit of units sold in initial public offering (in dollars per share)	21
Proceeds from sale of common units, net of offering costs							338,000,000	32,400,000
Offering costs							500,000
Number of units repurchased	175,000
Units outstanding after completion of IPO	8,864,222	88,545,764		73,421,309	47,703,313
Common Units | Repayment of advances under acquisition credit facility
Initial Public Offering
Number of units sold in public offering	3,850,000
Proceeds from sale of common units, net of offering costs	71,900,000
Offering costs	9,000,000
Common Units | Redemption of common units
Initial Public Offering
Number of units sold in public offering	175,000
Proceeds from sale of common units, net of offering costs	3,400,000
Subordinated Units
Partnership Equity
Subordinated units, conversion ratio		1		1
Initial Public Offering
Units outstanding after completion of IPO	5,919,346			5,919,346	5,919,346

Equity_Details_2

Equity (Details 2) (USD $)

6 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2012

Dec. 02, 2013

Sep. 23, 2013

Jul. 05, 2013

Oct. 03, 2011

Nov. 01, 2011

Jan. 03, 2012

Nov. 12, 2012

Jan. 11, 2013

Aug. 02, 2013

Jun. 23, 2014

17-May-11

Jul. 31, 2014

Common Units Issued in Business Combinations

Proceeds from sale of units, after underwriting discounts and commissions and offering costs

$370,446,000

$415,089,000

$650,155,000

($642,000)

$74,759,000

Common Units

Common Units Issued in Business Combinations

Number of units sold in public offering

4,100,000

10,350,000

Proceeds from sale of units, after underwriting discounts and commissions and offering costs

235,100,000

127,600,000

287,500,000

Underwriting discounts and commissions

5,000,000

12,000,000

Offering costs

4,900,000

200,000

700,000

Number of units sold in private placement

8,110,848

Osterman | Common Units

Common Units Issued in Business Combinations

Common units issued

4,000,000

4,000,000

SemStream | Common Units

Common Units Issued in Business Combinations

Common units issued

8,932,031

Pacer | Common Units

Common Units Issued in Business Combinations

Common units issued

1,500,000

Crude oil logistics and water solutions

Common Units Issued in Business Combinations

Common units issued

516,978

Pecos | Common Units

Common Units Issued in Business Combinations

Common units issued

1,834,414

Third Coast | Common Units

Common Units Issued in Business Combinations

Common units issued

344,680

Other Water Solutions

Common Units Issued in Business Combinations

Common units issued

222,381

Crude oil logistics

Common Units Issued in Business Combinations

Common units issued

175,211

OWL

Common Units Issued in Business Combinations

Common units issued

2,463,287

2,463,287

Common Units

Common Units Issued in Business Combinations

Common units issued

2,860,879

24,250,258

14,432,031

Number of units sold in public offering

8,000,000

4,025,000

Proceeds from sale of units, after underwriting discounts and commissions and offering costs

338,000,000

32,400,000

Underwriting discounts and commissions

12,300,000

Offering costs

$500,000

Number of units sold in private placement

767,100

Common Units | Osterman

Common Units Issued in Business Combinations

Common units issued

4,000,000

Common Units | SemStream

Common Units Issued in Business Combinations

Common units issued

8,932,031

Common Units | Pacer

Common Units Issued in Business Combinations

Common units issued

1,500,000

Common Units | High Sierra

Common Units Issued in Business Combinations

Common units issued

20,703,510

Common Units | Retail propane

Common Units Issued in Business Combinations

Common units issued

850,676

Common Units | Crude oil logistics and water solutions

Common Units Issued in Business Combinations

Common units issued

516,978

Common Units | Pecos

Common Units Issued in Business Combinations

Common units issued

1,834,414

Common Units | Third Coast

Common Units Issued in Business Combinations

Common units issued

344,680

Equity_Details_3

Equity (Details 3) (USD $)	0 Months Ended																			6 Months Ended	12 Months Ended		0 Months Ended
In Thousands, except Share data, unless otherwise specified	Jan. 23, 2014	Nov. 04, 2013	Oct. 23, 2013	Jul. 25, 2013	Apr. 25, 2013	Feb. 04, 2013	Jan. 24, 2013	Oct. 29, 2012	Oct. 17, 2012	Aug. 03, 2012	Jul. 24, 2012	Apr. 30, 2012	Apr. 18, 2012	Feb. 03, 2012	Jan. 24, 2012	Oct. 31, 2011	Oct. 21, 2011	Jul. 25, 2011	5-May-11	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2012	Apr. 24, 2014
Distributions
First level cash distribution percentage to holders of common units																					99.90%
First level cash distribution percentage to general partner																					0.10%
Second level cash distribution percentage to holders of subordinated units																					99.90%
Second level cash distribution percentage to general partner																					0.10%
Third level cash distribution percentage to all unitholders on pro rata basis																					99.90%
Third level cash distribution percentage to general partner																				0.10%	0.10%
Distributions
Distributions to partners prior to initial public offering																			$3,900			$3,850
Amount per unit (in dollars per unit)	$0.53		$0.51	$0.49	$0.48		$0.46		$0.45		$0.41		$0.36		$0.35		$0.34	$0.17
Number of equivalent units that were not eligible to receive a distribution		979,886				1,202,085		516,978		17,862,470		3,932,031		7,117,031		4,000,000
Subsequent event
Distributions
Amount per unit (in dollars per unit)																							$0.55
Minimum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.3375	0.3375
First target distribution | Minimum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.3375	0.3375
First target distribution | Maximum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.388125	0.388125
Second target distribution | Minimum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.388125	0.388125
Second target distribution | Maximum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.421875	0.421875
Third target distribution | Minimum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.421875	0.421875
Third target distribution | Maximum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.50625	0.50625
Thereafter | Minimum
Distributions
Total Quarterly Distribution per Unit (in dollars per unit)																				0.50625	0.50625
Limited Partners
Distributions
Marginal Percentage Interest In Distributions																				99.90%	99.90%
Amount Paid to Limited Partner	42,150		35,908	31,725	25,605		24,245		22,846		13,574		9,165		7,735		4,990	2,467
Limited Partners | Subsequent event
Distributions
Amount Paid to Limited Partner																							43,737
Limited Partners | Common Units
Distributions
Distributions to partners prior to initial public offering																						3,846
Limited Partners | First target distribution
Distributions
Marginal Percentage Interest In Distributions																				99.90%	99.90%
Limited Partners | Second target distribution
Distributions
Marginal Percentage Interest In Distributions																				86.90%	86.90%
Limited Partners | Third target distribution
Distributions
Marginal Percentage Interest In Distributions																				76.90%	76.90%
Limited Partners | Thereafter
Distributions
Marginal Percentage Interest In Distributions																				51.90%	51.90%
General Partner
Distributions
Marginal Percentage Interest In Distributions																				0.10%	0.10%
Distributions to partners prior to initial public offering																						4
Amount Paid to General Partner	4,283		2,491	1,739	1,189		927		707		134		10		10		5	3
General Partner | Subsequent event
Distributions
Amount Paid to General Partner																							$5,754
General Partner | First target distribution
Distributions
Marginal Percentage Interest In Distributions																				0.10%	0.10%
General Partner | Second target distribution
Distributions
Marginal Percentage Interest In Distributions																				13.10%	13.10%
General Partner | Third target distribution
Distributions
Marginal Percentage Interest In Distributions																				23.10%	23.10%
General Partner | Thereafter
Distributions
Marginal Percentage Interest In Distributions																				48.10%	48.10%

Equity_Details_4

Equity (Details 4) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013
Rollforward of the liability related to equity-based compensation
Balance at the beginning of the period			$10,012	$5,043	$5,043
Expense recorded			21,659		17,804	10,138
Value of units vested and issued			-18,763		-9,085	-3,627
Taxes paid on behalf of participants			-9,901		-3,750	-1,468
Balance at the end of the period	3,007		3,007		10,012	5,043
Maximum number of shares that may be issued as a percentage of outstanding common and subordinated units			10.00%		10.00%
Incremental amount that the maximum units deliverable may automatically increase under the plan, expressed as a percentage of issued and outstanding common and subordinated units			10.00%		10.00%
Restricted units
Equity-Based Incentive Compensation
Distributions on restricted units during the vesting period			0		0
Unvested restricted units at the beginning of the period (in shares)			1,311,100	1,444,900	1,444,900
Units granted (in shares)			333,903		494,000	1,684,400
Units vested and issued (in shares)			-438,009		-296,269	-156,802
Units withheld for employee taxes (in shares)			-231,194		-122,531	-61,698
Units forfeited (in shares)			-117,000		-209,000	-21,000
Unvested restricted units at the end of the period (in shares)	858,800		858,800		1,311,100	1,444,900
Number of awards vested			858,800		1,311,100
Estimate of forfeiture of unvested awards					95,000
Closing price (in dollars per share)	$39.37		$39.37		$37.53
Estimated stock-based compensation expense
2015					14,393
2016			11,516		11,279
2017			7,262		7,429
2018			2,237		2,310
2019			249		229
Total			27,607		35,640
Rollforward of the liability related to equity-based compensation
Expense recorded	$13,800	$3,200	$21,700	$10,300
Weighted-average grant date fair value of the awards (in dollars per share)	$35.16		$35.16		$33.78
Number of units available for issuance under the Long-Term Incentive Plan	7,100,000		7,100,000		6,200,000
Restricted units | July 1, 2014
Equity-Based Incentive Compensation
Number of awards vested					408,300
Restricted units | January 1, 2015
Equity-Based Incentive Compensation
Number of awards vested					4,000
Restricted units | July 1, 2015
Equity-Based Incentive Compensation
Number of awards vested			334,800		341,300
Restricted units | January 1, 2016
Equity-Based Incentive Compensation
Number of awards vested					4,000
Restricted units | July 1, 2016
Equity-Based Incentive Compensation
Number of awards vested			314,000		322,500
Restricted units | January 1, 2017
Equity-Based Incentive Compensation
Number of awards vested					4,000
Restricted units | July 1, 2017
Equity-Based Incentive Compensation
Number of awards vested			178,500		192,500
Restricted units | January 1, 2018
Equity-Based Incentive Compensation
Number of awards vested					4,000
Restricted units | July 1, 2018
Equity-Based Incentive Compensation
Number of awards vested			31,500		30,500

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments (Details) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Prepaid expenses and other current assets
Derivative assets (liabilities)
Net asset (liability)	$44,400	$43,500
Accrued expenses and other payables
Derivative assets (liabilities)
Net asset (liability)	36,300	34,600
Commodity contracts
Derivative assets (liabilities)
Net asset (liability)	42,659	8,490	-7,106
Commodity contracts | Prepaid expenses and other current assets
Derivative assets (liabilities)
Net asset (liability)	81,682	50,704	5,551
Commodity contracts | Other noncurrent assets
Derivative assets (liabilities)
Net asset (liability)			44
Commodity contracts | Accrued expenses and other payables
Derivative assets (liabilities)
Net asset (liability)	-39,023	-42,214	-12,701
Recurring | Commodity contracts
Assets:
Derivative Assets	100,021	54,595	10,858
Liabilities:
Derivative Liabilities	-43,658	-46,561	-16,604
Netting of counterparty contracts, assets	-4,635	-4,347	-3,503
Netting of counterparty contracts, liabilities	4,635	4,347	3,503
Cash collateral provided or held, assets	-13,704	456	-1,760
Cash collateral provided or held, liabilities			400
Commodity derivatives reported on condensed consolidated balance sheet, assets	81,682	50,704	5,595
Commodity derivatives reported on condensed consolidated balance sheet, liabilities	-39,023	-42,214	-12,701
Recurring | Level 1 | Commodity contracts
Assets:
Derivative Assets	48,632	4,990	947
Liabilities:
Derivative Liabilities	-5,378	-3,258	-3,324
Recurring | Level 2 | Commodity contracts
Assets:
Derivative Assets	51,389	49,605	9,911
Liabilities:
Derivative Liabilities	($38,280)	($43,303)	($13,280)

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments (Details 2) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Derivative contract information
Fair Value of Net Assets (Liabilities)	$56,363		$56,363		$8,034	($5,746)
Net cash collateral provided (held)	-13,704		-13,704		456	-1,360
Net fair value of commodity derivatives on condensed consolidated balance sheet	42,659		42,659		8,490	-7,106
Cross-commodity
Derivative contract information
Total Notional Units (Barrels)	-12,000		-12,000		140,000	430,000
Fair Value of Net Assets (Liabilities)	-1,283		-1,283		-1,876	-10,208
Crude oil fixed-price
Derivative contract information
Total Notional Units (Barrels)	-1,638,000		-1,638,000		-1,600,000	-144,000
Fair Value of Net Assets (Liabilities)	9,380		9,380		-2,796	1,033
Crude oil index
Derivative contract information
Total Notional Units (Barrels)	2,195,000		2,195,000		3,598,000	-91,000
Fair Value of Net Assets (Liabilities)	4,397		4,397		6,099	153
Propane fixed-price
Derivative contract information
Total Notional Units (Barrels)	1,238,000		1,238,000		60,000	-282,000
Fair Value of Net Assets (Liabilities)	53		53		1,753	3,197
Refined products fixed-price
Derivative contract information
Total Notional Units (Barrels)	-4,475,000		-4,475,000		732,000
Fair Value of Net Assets (Liabilities)	38,712		38,712		560
Renewable Products
Derivative contract information
Total Notional Units (Barrels)	-14,000		-14,000		106,000
Fair Value of Net Assets (Liabilities)	5,104		5,104		4,084
Other
Derivative contract information
Total Notional Units (Barrels)						8,000
Fair Value of Net Assets (Liabilities)					210	79
Commodity contracts
Derivative contract information
Net gains (losses) on derivatives	55,981	-10,672	38,496	-17,881	-43,655	-4,381	5,676
Natural gas fixed-price
Derivative contract information
Fair Value of Net Assets (Liabilities)					$210

Fair_Value_of_Financial_Instru4

Fair Value of Financial Instruments (Details 3) (USD $)	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Revolving Credit Facility
Interest Rate Risk
Outstanding debt	$1,100,000,000	$922,000,000
Interest rate (as a percent)	1.91%	1.98%
Interest Rate Risk | Variable Rate Debt
Interest Rate Risk
Change in interest rate that would result in an increase or decrease of annual interest expense (as a percent)	0.13%	0.13%
Increase or decrease in annual interest expense	$1,300,000	$1,200,000

Segments_Details

Segments (Details) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Segment information
Revenues	$5,380,526	$3,975,935	$2,743,445	$1,593,937	$1,385,957	$1,617,613	$1,338,208	$1,135,510	$326,436	$9,029,140	$2,979,894	$9,699,274	$4,417,767	$1,310,473
Depreciation and amortization	50,099			25,061						89,474	47,785	120,754	68,853	15,111
Operating Income	7,770			9,945						-12,785	2,603	106,565	87,307	15,030
Additions to property, plant and equipment including acquisitions (accrual basis)	605,642			111,781						660,509	146,298	390,989	326,896	200,457
Total assets	6,551,679	4,167,223				2,291,618				6,551,679		4,167,223	2,291,618
Long-lived assets, net	3,441,891	2,651,308				1,523,089				3,441,891		2,651,308	1,523,089
Crude oil logistics
Segment information
Depreciation and amortization	9,240			3,330						18,971	8,014	22,111	9,176
Operating Income	38			5,884						1,501	12,493	678	34,236
Additions to property, plant and equipment including acquisitions (accrual basis)	39,464			31,336						81,413	35,462	204,642	89,860
Total assets	2,079,380	1,723,812				801,351				2,079,380		1,723,812	801,351
Long-lived assets, net	996,615	980,978				357,230				996,615		980,978	357,230
Water solutions
Segment information
Depreciation and amortization												55,105	20,923
Operating Income												10,317	8,576
Additions to property, plant and equipment including acquisitions (accrual basis)												100,877	137,116
Total assets		875,714				466,412						875,714	466,412
Long-lived assets, net		848,479				453,909						848,479	453,909
Liquids
Segment information
Depreciation and amortization	3,384			2,672						6,585	5,376	11,018	11,085	3,661
Operating Income	10,929			14,605						10,016	12,490	71,888	30,336	9,735
Additions to property, plant and equipment including acquisitions (accrual basis)	1,911			13,209						3,070	28,316	52,560	15,129	50,276
Total assets	756,133	577,795				474,141				756,133		577,795	474,141
Long-lived assets, net	271,567	274,846				238,192				271,567		274,846	238,192
Retail propane
Segment information
Number of operating divisions										2		2
Depreciation and amortization	7,684			6,871						15,255	14,111	28,878	25,496	11,450
Operating Income	-3,062			-4,520						-4,648	-6,024	61,285	46,869	9,616
Additions to property, plant and equipment including acquisitions (accrual basis)	9,567			4,546						12,441	11,492	24,430	66,933	150,181
Total assets	506,958	541,832				513,301				506,958		541,832	513,301
Long-lived assets, net	436,621	438,324				441,762				436,621		438,324	441,762
Refined products
Segment information
Depreciation and amortization												109
Operating Income												4,080
Additions to property, plant and equipment including acquisitions (accrual basis)												719
Total assets		157,581										157,581
Long-lived assets, net		27,017										27,017
Renewables
Segment information
Depreciation and amortization												516
Operating Income												2,434
Additions to property, plant and equipment including acquisitions (accrual basis)												519
Total assets		145,649										145,649
Long-lived assets, net		33,703										33,703
Corporate and other
Segment information
Depreciation and amortization	301			750						1,237	1,490	3,017	2,173
Operating Income	-23,749			-8,937						-41,106	-22,312	-44,117	-32,710	-4,321
Additions to property, plant and equipment including acquisitions (accrual basis)	1,809			217						3,262	846	7,242	17,858
Total assets	61,198	144,840				36,413				61,198		144,840	36,413
Long-lived assets, net	53,705	47,961				31,996				53,705		47,961	31,996
Operating segment | Crude oil logistics | Crude oil sales
Segment information
Revenues	2,108,117			1,013,061						4,035,061	1,941,595	4,559,923	2,322,706
Operating segment | Crude oil logistics | Crude oil transportation and other
Segment information
Revenues	13,082			9,794						25,196	19,729	36,469	16,442
Operating segment | Water solutions | Water treatment and disposal
Segment information
Revenues												125,788	54,334
Operating segment | Water solutions | Water transportation
Segment information
Revenues												17,312	7,893
Operating segment | Liquids | Other revenues
Segment information
Revenues	6,814			9,250						12,530	18,114	31,062	33,954	2,462
Operating segment | Liquids | Propane sales
Segment information
Revenues	240,433			191,437						462,879	315,274	1,632,948	841,448	923,022
Operating segment | Liquids | Other product sales
Segment information
Revenues	306,625			308,606						594,984	558,459	1,231,965	858,276	251,627
Operating segment | Retail propane | Other revenues
Segment information
Revenues	8,276			8,198						15,457	15,898	35,918	35,856	17,370
Operating segment | Retail propane | Propane sales
Segment information
Revenues	48,552			40,651						100,578	87,342	388,225	288,410	175,417
Operating segment | Retail propane | Distillate sales
Segment information
Revenues	11,530			10,562						30,255	28,431	127,672	106,192	6,547
Operating segment | Refined products
Segment information
Revenues												1,180,895
Operating segment | Renewables
Segment information
Revenues												176,781
Operating segment | Corporate and other
Segment information
Revenues	1,333			1,485						2,794	2,959	437,713	4,233
Elimination of intersegment sales
Segment information
Revenues	($24,175)			($33,297)						($75,314)	($62,610)	($283,397)	($151,977)	($65,972)

Disposals_and_Impairments_Deta

Disposals and Impairments (Details) (USD $)	12 Months Ended	1 Months Ended
	Mar. 31, 2014	Feb. 26, 2014
	item
Liquids
Disposals and Impairments
Write down of property, plant and equipment	$5,300,000
Number of natural gas liquids terminals	1
Water solutions
Disposals and Impairments
Write down of property, plant and equipment	1,500,000
Number of water solutions facilities which experienced damage to property, plant and equipment	2
Gavilon Energy | Natural Gas Storage and Transportation Contracts
Disposals and Impairments
Payments for assignment of contracts	44,800,000
Liability recorded in the acquisition accounting	50,800,000
Amortization of contract liabilities through cost of sales	6,000,000
Gavilon Energy | Natural Gas Storage and Transportation Contracts | Corporate and other
Disposals and Impairments
Operating income	1,400,000
High Sierra
Disposals and Impairments
Proceeds from sale of business		10,800,000
Gain on sale of business		4,400,000
Gain on the sale of the business attributable to noncontrolling interest		1,600,000
High Sierra | Corporate and other
Disposals and Impairments
Operating income	$2,300,000

Transactions_with_Affiliates_D

Transactions with Affiliates (Details) (USD $)	12 Months Ended	0 Months Ended	12 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	Mar. 31, 2013	Jun. 19, 2012	Mar. 31, 2014	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2012
	item
Transactions with Affiliates
Receivables from affiliates	$22,883,000		$7,445,000	$41,706,000		$41,706,000
Payables to related parties	6,900,000		76,846,000	85,307,000		85,307,000
Cash paid	14,000,000
Number of business acquired	2
Amount paid to employee for non compete agreement	5,000,000
High Sierra Energy, LP
Transactions with Affiliates
Cash paid		91,800,000
Cash acquired		5,000,000
Common units issued		18,018,468
Liabilities assumed in the form of non-compete agreements		97,400,000
Crude oil logistics business owned by an employee
Transactions with Affiliates
Cash paid			11,000,000
SemGroup
Transactions with Affiliates
Right to appoint number of members to the Board of Directors of the entity's general partner by related party			2
Sales to related party	32,431,000		306,780,000	43,427,000	3,780,000	117,233,000	3,780,000	29,200,000
Purchase from related parties	60,425,000		445,951,000	45,730,000	28,377,000	118,997,000	47,916,000	23,800,000
Receivables from affiliates			7,303,000	39,331,000		39,331,000
Payables to related parties	4,601,000		27,738,000	44,015,000		44,015,000
SemGroup and equity method investees
Transactions with Affiliates
Payables to related parties			27,738,000
Entities affiliated with management
Transactions with Affiliates
Increase in property, plant and equipment			8,200,000			5,800,000
Sales to related party	16,828,000		110,824,000	1,706,000	58,769,000	1,854,000	109,872,000
Purchase from related parties	60,942,000		120,038,000	3,845,000	48,522,000	6,984,000	56,346,000
Receivables from affiliates	22,883,000		142,000	1,705,000		1,705,000
Payables to related parties	2,299,000		654,000	1,743,000		1,743,000
General Partner
Transactions with Affiliates
Common units issued		2,685,042
Amount paid		50,000,000
General Partner | High Sierra Energy, LP
Transactions with Affiliates
Cash paid		$50,000,000

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Total revenues (in dollars)	$5,380,526	$3,975,935	$2,743,445	$1,593,937	$1,385,957	$1,617,613	$1,338,208	$1,135,510	$326,436	$9,029,140	$2,979,894	$9,699,274	$4,417,767	$1,310,473
Total cost of sales	5,179,465	3,764,744	2,576,029	1,488,850	1,303,076	1,481,890	1,204,545	1,053,690	298,985	8,713,518	2,791,926	9,132,699	4,039,110	1,217,023
Net income (loss)	-15,879	43,146	24,052	-932	-17,508	22,341	40,477	10,082	-24,710	-55,789	-18,440	48,758	48,190	7,864
Net income (loss) attributable to parent equity (in dollars)	($19,224)	$42,331	$23,898	($941)	($17,633)	$22,341	$40,176	$10,073	($24,650)	($59,199)	($18,574)	$47,655	$47,940	$7,876
Common Units
Earnings (loss) per unit, basic and diluted -
Earnings (loss) per unit, basic and diluted -	($0.34)	$0.46	$0.27	($0.05)	($0.35)	$0.39	$0.75	$0.18	($0.76)	($0.93)	($0.37)	$0.51	$0.96	$0.32
Weighted average units outstanding (in shares)	88,331,653	73,421,309	67,941,726	58,909,389	47,703,313	47,665,015	46,364,381	44,831,836	26,529,133	81,267,742	53,336,969	61,970,471	41,353,574	15,169,983
Subordinated Units
Earnings (loss) per unit, basic and diluted -
Earnings (loss) per unit, basic and diluted -		$0.46	$0.23	($0.09)	($0.46)	$0.39	$0.75	$0.18	($0.77)			$0.32	$0.93	$0.58
Weighted average units outstanding (in shares)	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346		5,919,346	5,919,346	5,919,346	5,175,384

Condensed_Consolidating_Guaran2

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011	Oct. 16, 2013
CURRENT ASSETS:
Cash and cash equivalents	$11,823,000	$10,440,000	$5,528,000	$11,561,000	$7,832,000	$16,337,000
Accounts receivable - trade, net of allowance for doubtful accounts	1,433,117,000	900,904,000		562,757,000
Accounts receivable - affiliates	41,706,000	7,445,000		22,883,000
Inventories	941,589,000	310,160,000		126,895,000
Prepaid expenses and other current assets	156,818,000	80,350,000		37,891,000
Total current assets	2,585,053,000	1,309,299,000		761,987,000
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,433,313,000	829,346,000		526,437,000
GOODWILL	1,170,490,000	1,107,006,000		555,220,000	167,245,000	8,568,000
INTANGIBLE ASSETS, net of accumulated amortization	838,088,000	714,956,000		441,432,000
INVESTMENTS IN UNCONSOLIDATED ENTITIES	482,644,000	189,821,000
OTHER NONCURRENT ASSETS	42,091,000	16,795,000		6,542,000
Total assets	6,551,679,000	4,167,223,000		2,291,618,000
CURRENT LIABILITIES:
Accounts payable - trade	1,345,024,000	740,211,000		536,055,000
Accounts payable - affiliates	85,307,000	76,846,000		6,900,000
Accrued expenses and other payables	218,482,000	141,690,000		85,606,000
Advance payments received from customers	106,105,000	29,965,000		22,372,000
Current maturities of long-term debt	5,062,000	7,080,000		8,626,000
Total current liabilities	1,759,980,000	995,792,000		659,559,000
LONG-TERM DEBT, net of current maturities	2,437,351,000	1,629,834,000		740,436,000
OTHER NONCURRENT LIABILITIES	39,518,000	9,744,000		2,205,000
EQUITY
Partners' equity (deficit)	1,746,133,000	1,526,815,000		883,654,000
Accumulated other comprehensive income (loss)	-73,000	-236,000		24,000
Noncontrolling interests	568,770,000	5,274,000		5,740,000
Total equity	2,314,830,000	1,531,853,000		889,418,000	405,329,000	47,353,000
Total liabilities and equity	6,551,679,000	4,167,223,000		2,291,618,000
Unsecured Notes
EQUITY
Debt issued							450,000,000
Fixed interest rate (as a percent)							6.88%
NGL Energy Partners LP (Parent) | Unsecured Notes
EQUITY
Debt issued		450,000,000
Fixed interest rate (as a percent)		6.88%
Reportable Entity | NGL Energy Partners LP (Parent)
CURRENT ASSETS:
Cash and cash equivalents	2,841,000	1,181,000	1,346,000		41,000	41,000
Total current assets	2,841,000	1,181,000
INTANGIBLE ASSETS, net of accumulated amortization	1,307,000	1,169,000		717,000
NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893,000	327,281,000		237,736,000
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573,000	1,447,502,000		895,779,000
Total assets	1,996,614,000	1,777,133,000		1,134,232,000
CURRENT LIABILITIES:
Accrued expenses and other payables	554,000	554,000		554,000
Total current liabilities	554,000	554,000		554,000
LONG-TERM DEBT, net of current maturities	250,000,000	250,000,000		250,000,000
EQUITY
Partners' equity (deficit)	1,746,060,000	1,526,579,000		883,678,000
Total equity	1,746,060,000	1,526,579,000		883,678,000
Total liabilities and equity	1,996,614,000	1,777,133,000		1,134,232,000
Reportable Entity | NGL Energy Finance Corp
CURRENT ASSETS:
INTANGIBLE ASSETS, net of accumulated amortization	17,619,000	11,552,000
NET INTERCOMPANY RECEIVABLES (PAYABLES)	849,526,000	437,714,000
Total assets	867,145,000	449,266,000
CURRENT LIABILITIES:
Accrued expenses and other payables	19,021,000	14,266,000
Total current liabilities	19,021,000	14,266,000
LONG-TERM DEBT, net of current maturities	850,000,000	450,000,000
EQUITY
Partners' equity (deficit)	-1,876,000	-15,000,000
Total equity	-1,876,000	-15,000,000
Total liabilities and equity	867,145,000	449,266,000
Reportable Entity | Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	7,823,000	8,728,000	3,904,000	11,206,000	7,594,000	16,174,000
Accounts receivable - trade, net of allowance for doubtful accounts	1,419,442,000	887,789,000		561,560,000
Accounts receivable - affiliates	41,035,000	7,445,000		22,883,000
Inventories	937,814,000	306,434,000		126,024,000
Prepaid expenses and other current assets	155,332,000	80,294,000		37,784,000
Total current assets	2,561,446,000	1,290,690,000		759,457,000
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	863,694,000	764,014,000		497,743,000
GOODWILL	1,139,374,000	1,105,008,000		553,222,000
INTANGIBLE ASSETS, net of accumulated amortization	778,960,000	700,603,000		439,365,000
INVESTMENTS IN UNCONSOLIDATED ENTITIES	214,234,000	189,821,000
NET INTERCOMPANY RECEIVABLES (PAYABLES)	-1,026,605,000	-720,737,000		-233,294,000
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	10,470,000	17,673,000		20,371,000
OTHER NONCURRENT ASSETS	40,035,000	16,674,000		6,542,000
Total assets	4,581,608,000	3,363,746,000		2,043,406,000
CURRENT LIABILITIES:
Accounts payable - trade	1,333,780,000	726,252,000		534,164,000
Accounts payable - affiliates	85,237,000	73,703,000		6,900,000
Accrued expenses and other payables	186,226,000	124,923,000		83,001,000
Advance payments received from customers	105,597,000	29,891,000		22,364,000
Current maturities of long-term debt	5,004,000	7,058,000		8,610,000
Total current liabilities	1,715,844,000	961,827,000		655,039,000
LONG-TERM DEBT, net of current maturities	1,085,155,000	929,754,000		490,433,000
OTHER NONCURRENT LIABILITIES	35,160,000	9,663,000		2,155,000
EQUITY
Partners' equity (deficit)	1,745,450,000	1,462,691,000		895,779,000
Accumulated other comprehensive income (loss)	-1,000	-189,000
Total equity	1,745,449,000	1,462,502,000		895,779,000
Total liabilities and equity	4,581,608,000	3,363,746,000		2,043,406,000
Reportable Entity | Non-Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	1,159,000	531,000	278,000	355,000	197,000	122,000
Accounts receivable - trade, net of allowance for doubtful accounts	13,675,000	13,115,000		1,197,000
Accounts receivable - affiliates	671,000
Inventories	3,775,000	3,726,000		871,000
Prepaid expenses and other current assets	1,486,000	56,000		107,000
Total current assets	20,766,000	17,428,000		2,530,000
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	569,619,000	65,332,000		28,694,000
GOODWILL	31,116,000	1,998,000		1,998,000
INTANGIBLE ASSETS, net of accumulated amortization	40,202,000	1,632,000		1,350,000
INVESTMENTS IN UNCONSOLIDATED ENTITIES	268,410,000
NET INTERCOMPANY RECEIVABLES (PAYABLES)	-71,814,000	-44,258,000		-4,442,000
OTHER NONCURRENT ASSETS	2,056,000	121,000
Total assets	860,355,000	42,253,000		30,130,000
CURRENT LIABILITIES:
Accounts payable - trade	11,244,000	13,959,000		1,891,000
Accounts payable - affiliates	70,000	3,143,000
Accrued expenses and other payables	12,681,000	1,947,000		2,051,000
Advance payments received from customers	508,000	74,000		8,000
Current maturities of long-term debt	58,000	22,000		16,000
Total current liabilities	24,561,000	19,145,000		3,966,000
LONG-TERM DEBT, net of current maturities	252,196,000	80,000		3,000
OTHER NONCURRENT LIABILITIES	4,358,000	81,000		50,000
EQUITY
Partners' equity (deficit)	579,312,000	22,994,000		26,087,000
Accumulated other comprehensive income (loss)	-72,000	-47,000		24,000
Total equity	579,240,000	22,947,000		26,111,000
Total liabilities and equity	860,355,000	42,253,000		30,130,000
Consolidating Adjustments
CURRENT ASSETS:
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	-1,754,043,000	-1,465,175,000		-916,150,000
Total assets	-1,754,043,000	-1,465,175,000		-916,150,000
EQUITY
Partners' equity (deficit)	-2,322,813,000	-1,470,449,000		-921,890,000
Noncontrolling interests	568,770,000	5,274,000		5,740,000
Total equity	-1,754,043,000	-1,465,175,000		-916,150,000
Total liabilities and equity	($1,754,043,000)	($1,465,175,000)		($916,150,000)

Condensed_Consolidating_Guaran3

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 2) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Oct. 16, 2013
Condensed Consolidating Statement of Operations
REVENUES	$5,380,526,000	$3,975,935,000	$2,743,445,000	$1,593,937,000	$1,385,957,000	$1,617,613,000	$1,338,208,000	$1,135,510,000	$326,436,000	$9,029,140,000	$2,979,894,000	$9,699,274,000	$4,417,767,000	$1,310,473,000
COST OF SALES	5,179,465,000	3,764,744,000	2,576,029,000	1,488,850,000	1,303,076,000	1,481,890,000	1,204,545,000	1,053,690,000	298,985,000	8,713,518,000	2,791,926,000	9,132,699,000	4,039,110,000	1,217,023,000
OPERATING COSTS AND EXPENSES:
Operating	101,553,000			55,769,000						169,421,000	104,814,000	259,396,000	169,799,000	47,300,000
General and administrative	41,639,000			14,312,000						69,512,000	32,766,000	79,860,000	52,698,000	16,009,000
Depreciation and amortization	50,099,000			25,061,000						89,474,000	47,785,000	120,754,000	68,853,000	15,111,000
Operating Income (Loss)	7,770,000			9,945,000						-12,785,000	2,603,000	106,565,000	87,307,000	15,030,000
OTHER INCOME (EXPENSE):
Earnings from unconsolidated entities	3,697,000									6,262,000		1,898,000
Interest expense	-28,651,000			-11,060,000						-49,145,000	-21,682,000	-58,854,000	-32,994,000	-7,620,000
Loss on early extinguishment of debt													-5,769,000
Other, net	-617,000			419,000						-1,008,000	469,000	86,000	1,521,000	1,055,000
Loss before Income Taxes	-17,801,000			-696,000						-56,676,000	-18,610,000	49,695,000	50,065,000	8,465,000
INCOME TAX PROVISION	1,922,000			-236,000						887,000	170,000	-937,000	-1,875,000	-601,000
Net Loss	-15,879,000	43,146,000	24,052,000	-932,000	-17,508,000	22,341,000	40,477,000	10,082,000	-24,710,000	-55,789,000	-18,440,000	48,758,000	48,190,000	7,864,000
NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056,000			-2,451,000						-20,437,000	-4,139,000	-14,148,000	-2,917,000	-8,000
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-3,345,000			-9,000						-3,410,000	-134,000	-1,103,000	-250,000	12,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280,000			-3,392,000						-79,636,000	-22,713,000	33,507,000	45,023,000	7,868,000
Unsecured Notes
OTHER INCOME (EXPENSE):
Debt issued															450,000,000
Fixed interest rate (as a percent)															6.88%
NGL Energy Partners LP (Parent) | Unsecured Notes
OTHER INCOME (EXPENSE):
Debt issued		450,000,000										450,000,000
Fixed interest rate (as a percent)		6.88%										6.88%
Reportable Entity | NGL Energy Partners LP (Parent)
OTHER INCOME (EXPENSE):
Interest expense	-4,067,000			-4,179,000						-8,313,000	-8,368,000	-16,818,000	-13,041,000
Loss before Income Taxes	-4,067,000			-4,179,000						-8,313,000	-8,368,000	-16,818,000	-13,041,000
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	-15,157,000			3,238,000						-50,886,000	-10,206,000	64,473,000	60,981,000	7,876,000
Net Loss	-19,224,000			-941,000						-59,199,000	-18,574,000	47,655,000	47,940,000	7,876,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	-19,224,000			-941,000						-59,199,000	-18,574,000	47,655,000	47,940,000	7,876,000
Reportable Entity | NGL Energy Finance Corp
OTHER INCOME (EXPENSE):
Interest expense	-13,134,000									-21,280,000		-15,000,000
Loss before Income Taxes	-13,134,000									-21,280,000		-15,000,000
Net Loss	-13,134,000									-21,280,000		-15,000,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	-13,134,000									-21,280,000		-15,000,000
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	5,325,186,000			1,546,226,000						8,952,772,000	2,914,531,000	9,560,124,000	4,409,198,000	1,310,473,000
COST OF SALES	5,161,935,000			1,445,442,000						8,676,881,000	2,735,890,000	9,011,011,000	4,038,251,000	1,217,248,000
OPERATING COSTS AND EXPENSES:
Operating	84,300,000			52,979,000						150,919,000	99,710,000	253,214,000	164,944,000	47,162,000
General and administrative	36,360,000			14,089,000						64,124,000	32,297,000	77,756,000	52,461,000	15,823,000
Depreciation and amortization	38,999,000			23,970,000						77,545,000	46,000,000	117,573,000	66,916,000	14,964,000
Operating Income (Loss)	3,592,000			9,746,000						-16,697,000	634,000	100,570,000	86,626,000	15,276,000
OTHER INCOME (EXPENSE):
Earnings from unconsolidated entities	2,310,000									4,875,000		1,898,000
Interest expense	-9,956,000			-6,880,000						-18,058,000	-13,309,000	-27,031,000	-19,951,000	-7,619,000
Loss on early extinguishment of debt													-5,769,000
Other, net	-524,000			528,000						-1,056,000	627,000	202,000	1,666,000	1,100,000
Loss before Income Taxes	-4,578,000			3,394,000						-30,936,000	-12,048,000	75,639,000	62,572,000	8,757,000
INCOME TAX PROVISION	1,951,000			-236,000						993,000	170,000	-937,000	-1,875,000	-601,000
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	604,000			80,000						337,000	1,672,000	4,771,000	284,000	-280,000
Net Loss	-2,023,000			3,238,000						-29,606,000	-10,206,000	79,473,000	60,981,000	7,876,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	-2,023,000			3,238,000						-29,606,000	-10,206,000	79,473,000	60,981,000	7,876,000
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	55,364,000			47,735,000						76,421,000	65,421,000	139,519,000	8,878,000	225,000
COST OF SALES	17,554,000			43,432,000						36,690,000	56,094,000	122,057,000	1,168,000
OPERATING COSTS AND EXPENSES:
Operating	17,253,000			2,790,000						18,502,000	5,104,000	6,182,000	4,855,000	138,000
General and administrative	5,279,000			223,000						5,388,000	469,000	2,104,000	237,000	186,000
Depreciation and amortization	11,100,000			1,091,000						11,929,000	1,785,000	3,181,000	1,937,000	147,000
Operating Income (Loss)	4,178,000			199,000						3,912,000	1,969,000	5,995,000	681,000	-246,000
OTHER INCOME (EXPENSE):
Earnings from unconsolidated entities	1,387,000									1,387,000
Interest expense	-1,506,000			-13,000						-1,517,000	-28,000	-51,000	-48,000	-46,000
Other, net	-81,000			-97,000						71,000	-135,000	-70,000	-99,000
Loss before Income Taxes	3,978,000			89,000						3,853,000	1,806,000	5,874,000	534,000	-292,000
INCOME TAX PROVISION	-29,000									-106,000
Net Loss	3,949,000			89,000						3,747,000	1,806,000	5,874,000	534,000	-292,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	3,949,000			89,000						3,747,000	1,806,000	5,874,000	534,000	-292,000
Consolidating Adjustments
Condensed Consolidating Statement of Operations
REVENUES	-24,000			-24,000						-53,000	-58,000	-369,000	-309,000	-225,000
COST OF SALES	-24,000			-24,000						-53,000	-58,000	-369,000	-309,000	-225,000
OTHER INCOME (EXPENSE):
Interest expense	12,000			12,000						23,000	23,000	46,000	46,000	45,000
Other, net	-12,000			-12,000						-23,000	-23,000	-46,000	-46,000	-45,000
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	14,553,000			-3,318,000						50,549,000	8,534,000	-69,244,000	-61,265,000	-7,596,000
Net Loss	14,553,000			-3,318,000						50,549,000	8,534,000	-69,244,000	-61,265,000	-7,596,000
NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056,000			-2,451,000						-20,437,000	-4,139,000	-14,148,000	-2,917,000	-8,000
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-3,345,000			-9,000						-3,410,000	-134,000	-1,103,000	-250,000	12,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	$152,000			($5,778,000)						$26,702,000	$4,261,000	($84,495,000)	($64,432,000)	($7,592,000)

Condensed_Consolidating_Guaran4

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 3) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Oct. 16, 2013
Condensed Consolidating Statements of Comprehensive Income
Net loss	($15,879,000)	$43,146,000	$24,052,000	($932,000)	($17,508,000)	$22,341,000	$40,477,000	$10,082,000	($24,710,000)	($55,789,000)	($18,440,000)	$48,758,000	$48,190,000	$7,864,000
Other comprehensive income (loss)	-22,000			-5,000						163,000	-30,000	-260,000	-7,000	-25,000
Comprehensive loss	-15,901,000			-937,000						-55,626,000	-18,470,000	48,498,000	48,183,000	7,839,000
Unsecured Notes
Condensed Consolidating Statements of Comprehensive Income
Debt issued															450,000,000
Fixed interest rate (as a percent)															6.88%
NGL Energy Partners LP (Parent) | Unsecured Notes
Condensed Consolidating Statements of Comprehensive Income
Debt issued		450,000,000										450,000,000
Fixed interest rate (as a percent)		6.88%										6.88%
Reportable Entity | NGL Energy Partners LP (Parent)
Condensed Consolidating Statements of Comprehensive Income
Net loss	-19,224,000			-941,000						-59,199,000	-18,574,000	47,655,000	47,940,000	7,876,000
Comprehensive loss	-19,224,000			-941,000						-59,199,000	-18,574,000	47,655,000	47,940,000	7,876,000
Reportable Entity | NGL Energy Finance Corp
Condensed Consolidating Statements of Comprehensive Income
Net loss	-13,134,000									-21,280,000		-15,000,000
Comprehensive loss	-13,134,000									-21,280,000		-15,000,000
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statements of Comprehensive Income
Net loss	-2,023,000			3,238,000						-29,606,000	-10,206,000	79,473,000	60,981,000	7,876,000
Other comprehensive income (loss)	4,000									189,000		-189,000
Comprehensive loss	-2,019,000			3,238,000						-29,417,000	-10,206,000	79,284,000	60,981,000	7,876,000
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statements of Comprehensive Income
Net loss	3,949,000			89,000						3,747,000	1,806,000	5,874,000	534,000	-292,000
Other comprehensive income (loss)	-26,000			-5,000						-26,000	-30,000	-71,000	-7,000	-25,000
Comprehensive loss	3,923,000			84,000						3,721,000	1,776,000	5,803,000	527,000	-317,000
Consolidating Adjustments
Condensed Consolidating Statements of Comprehensive Income
Net loss	14,553,000			-3,318,000						50,549,000	8,534,000	-69,244,000	-61,265,000	-7,596,000
Comprehensive loss	$14,553,000			($3,318,000)						$50,549,000	$8,534,000	($69,244,000)	($61,265,000)	($7,596,000)

Condensed_Consolidating_Guaran5

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 4) (USD $)	6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Oct. 16, 2013
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	($61,635,000)	($48,744,000)	$85,236,000	$132,634,000	$90,329,000
INVESTING ACTIVITIES:
Purchases of long-lived assets	-82,851,000	-67,399,000	-165,148,000	-72,475,000	-7,544,000
Acquisitions of businesses, including acquired working capital, net of cash acquired	-658,764,000	-392,605,000	-1,268,810,000	-490,805,000	-297,401,000
Cash flows from commodity derivatives			-35,956,000	11,579,000	6,464,000
Proceeds from sales of assets	8,741,000	2,224,000	24,660,000	5,080,000	1,238,000
Investments in unconsolidated entities	-26,390,000		-11,515,000
Distributions of capital from unconsolidated entities			1,591,000
Other			-195,000		346,000
Net cash used in investing activities	-750,288,000	-476,854,000	-1,455,373,000	-546,621,000	-296,897,000
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,979,500,000	1,061,500,000	2,545,500,000	1,227,975,000	478,900,000
Payments on revolving credit facilities	-1,804,000,000	-893,000,000	-2,101,000,000	-964,475,000	-329,900,000
Issuances of notes	400,000,000		450,000,000	250,000,000
Proceeds from borrowings on other long-term debt		880,000	880,000	653,000
Payments on other long-term debt	-4,175,000	-4,507,000	-8,819,000	-4,837,000	-1,278,000
Debt issuance costs	-9,198,000	-2,218,000	-24,595,000	-20,189,000	-2,380,000
Contributions	395,000	2,444,000	2,825,000	913,000	440,000
Distributions			-145,930,000	-71,682,000	-19,060,000
Proceeds from sale of common units, net of offering costs	370,446,000	415,089,000	650,155,000	-642,000	74,759,000
Repurchase of common units					-3,418,000
Net cash provided by financing activities	813,306,000	519,565,000	1,369,016,000	417,716,000	198,063,000
Net increase (decrease) in cash and cash equivalents	1,383,000	-6,033,000	-1,121,000	3,729,000	-8,505,000
Cash and cash equivalents, beginning of period	10,440,000	11,561,000	11,561,000	7,832,000	16,337,000
Cash and cash equivalents, end of period	11,823,000	5,528,000	10,440,000	11,561,000	7,832,000
Unsecured Notes
FINANCING ACTIVITIES:
Debt issued						450,000,000
Fixed interest rate (as a percent)						6.88%
NGL Energy Partners LP (Parent) | Unsecured Notes
FINANCING ACTIVITIES:
Debt issued			450,000,000
Fixed interest rate (as a percent)			6.88%
Reportable Entity | NGL Energy Partners LP (Parent)
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-8,180,000	-8,312,000	-16,625,000	-12,428,000
INVESTING ACTIVITIES:
Acquisitions of businesses, including acquired working capital, net of cash acquired		-334,085,000	-334,154,000	-452,087,000	-291,097,000
Net cash used in investing activities		-334,085,000	-334,154,000	-452,087,000	-291,097,000
FINANCING ACTIVITIES:
Issuances of notes				250,000,000
Debt issuance costs	-269,000	-133,000	-645,000	-777,000
Contributions	395,000	504,000	765,000	510,000
Distributions			-145,090,000	-71,608,000	-19,060,000
Proceeds from sale of common units, net of offering costs	370,446,000	415,089,000	650,155,000	-642,000	74,759,000
Repurchase of common units					-3,418,000
Net changes in advances with consolidated entities	-249,724,000	-11,459,000	-153,225,000	286,991,000	238,816,000
Net cash provided by financing activities	9,840,000	343,743,000	351,960,000	464,474,000	291,097,000
Net increase (decrease) in cash and cash equivalents	1,660,000	1,346,000	1,181,000	-41,000
Cash and cash equivalents, beginning of period	1,181,000			41,000	41,000
Cash and cash equivalents, end of period	2,841,000	1,346,000	1,181,000		41,000
Reportable Entity | NGL Energy Finance Corp
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-15,383,000
FINANCING ACTIVITIES:
Issuances of notes	400,000,000		450,000,000
Debt issuance costs	-7,209,000		-12,286,000
Net changes in advances with consolidated entities	-377,408,000		-437,714,000
Net cash provided by financing activities	15,383,000
Reportable Entity | Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-56,019,000	-44,607,000	99,754,000	140,794,000	90,477,000
INVESTING ACTIVITIES:
Purchases of long-lived assets	-81,710,000	-37,180,000	-118,455,000	-59,903,000	-6,667,000
Acquisitions of businesses, including acquired working capital, net of cash acquired	-657,514,000	-56,237,000	-932,373,000	-38,718,000	-6,304,000
Cash flows from commodity derivatives			-35,956,000	11,579,000	6,464,000
Proceeds from sales of assets	8,741,000	2,223,000	12,884,000	5,080,000	1,238,000
Investments in unconsolidated entities	-6,106,000		-11,515,000
Distributions of capital from unconsolidated entities			1,591,000
Other			540,000		346,000
Net cash used in investing activities	-729,488,000	-110,268,000	-1,083,284,000	-81,962,000	-4,923,000
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,923,500,000	1,061,500,000	2,545,500,000	1,227,975,000	478,900,000
Payments on revolving credit facilities	-1,766,000,000	-893,000,000	-2,101,000,000	-964,475,000	-329,900,000
Proceeds from borrowings on other long-term debt		780,000	780,000	634,000
Payments on other long-term debt	-4,173,000	-4,499,000	-8,802,000	-4,837,000	-1,278,000
Debt issuance costs	-1,720,000	-2,085,000	-11,664,000	-19,412,000	-2,380,000
Net changes in advances with consolidated entities	632,995,000	-15,123,000	556,238,000	-295,105,000	-239,476,000
Net cash provided by financing activities	784,602,000	147,573,000	981,052,000	-55,220,000	-94,134,000
Net increase (decrease) in cash and cash equivalents	-905,000	-7,302,000	-2,478,000	3,612,000	-8,580,000
Cash and cash equivalents, beginning of period	8,728,000	11,206,000	11,206,000	7,594,000	16,174,000
Cash and cash equivalents, end of period	7,823,000	3,904,000	8,728,000	11,206,000	7,594,000
Reportable Entity | Non-Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	17,947,000	4,175,000	2,107,000	4,268,000	-148,000
INVESTING ACTIVITIES:
Purchases of long-lived assets	-1,141,000	-30,219,000	-46,693,000	-12,572,000	-877,000
Acquisitions of businesses, including acquired working capital, net of cash acquired	-1,250,000	-2,283,000	-2,283,000
Proceeds from sales of assets		1,000	11,776,000
Investments in unconsolidated entities	-20,284,000
Other			-735,000
Net cash used in investing activities	-20,800,000	-32,501,000	-37,935,000	-12,572,000	-877,000
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	56,000,000
Payments on revolving credit facilities	-38,000,000
Proceeds from borrowings on other long-term debt		100,000	100,000	19,000
Payments on other long-term debt	-2,000	-8,000	-17,000
Contributions		1,940,000	2,060,000	403,000	440,000
Distributions			-840,000	-74,000
Net changes in advances with consolidated entities	-5,863,000	26,582,000	34,701,000	8,114,000	660,000
Net cash provided by financing activities	3,481,000	28,249,000	36,004,000	8,462,000	1,100,000
Net increase (decrease) in cash and cash equivalents	628,000	-77,000	176,000	158,000	75,000
Cash and cash equivalents, beginning of period	531,000	355,000	355,000	197,000	122,000
Cash and cash equivalents, end of period	$1,159,000	$278,000	$531,000	$355,000	$197,000

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$11,823	$10,440	$5,528	$11,561	$7,832	$16,337
Accounts receivable - trade, net of allowance for doubtful accounts of $2,816 and $2,822, respectively	1,433,117	900,904		562,757
Accounts receivable - affiliates	41,706	7,445		22,883
Inventories	941,589	310,160		126,895
Prepaid expenses and other current assets	156,818	80,350		37,891
Total current assets	2,585,053	1,309,299		761,987
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $153,057 and $109,564, respectively	1,433,313	829,346		526,437
GOODWILL	1,170,490	1,107,006		555,220	167,245	8,568
INTANGIBLE ASSETS, net of accumulated amortization of $166,484 and $116,728, respectively	838,088	714,956		441,432
INVESTMENTS IN UNCONSOLIDATED ENTITIES	482,644	189,821
OTHER NONCURRENT ASSETS	42,091	16,795		6,542
Total assets	6,551,679	4,167,223		2,291,618
CURRENT LIABILITIES:
Accounts payable - trade	1,345,024	740,211		536,055
Accounts payable - affiliates	85,307	76,846		6,900
Accrued expenses and other payables	218,482	141,690		85,606
Advance payments received from customers	106,105	29,965		22,372
Current maturities of long-term debt	5,062	7,080		8,626
Total current liabilities	1,759,980	995,792		659,559
LONG-TERM DEBT, net of current maturities	2,437,351	1,629,834		740,436
OTHER NONCURRENT LIABILITIES	39,518	9,744		2,205
COMMITMENTS AND CONTINGENCIES
EQUITY, per accompanying statement:
General partner, representing a 0.1% interest, 88,634 and 79,420 notional units at September 30, 2014 and March 31, 2014, respectively	-39,690	-45,287		-50,497
Limited partners, representing a 99.9% interest -
Accumulated other comprehensive loss	-73	-236		24
Noncontrolling interests	568,770	5,274		5,740
Total equity	2,314,830	1,531,853		889,418	405,329	47,353
Total liabilities and equity	6,551,679	4,167,223		2,291,618
Common Units
Limited partners, representing a 99.9% interest -
Limited partners, representing a 99.9% interest -	1,785,823	1,570,074		920,998
Subordinated Units
Limited partners, representing a 99.9% interest -
Limited partners, representing a 99.9% interest -		$2,028		$13,153

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	0 Months Ended	6 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	17-May-11	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
Accounts receivable - trade, allowance for doubtful accounts (in dollars)		$2,816	$2,822	$1,760
PROPERTY, PLANT AND EQUIPMENT, accumulated depreciation (in dollars)		153,057	109,564	50,127
INTANGIBLE ASSETS, accumulated amortization (in dollars)		$166,484	$116,728	$44,155
General partner, interest (as a percent)	0.10%	0.10%	0.10%	0.10%
General partner, notional units outstanding		88,634	79,420	53,676
Limited partners, interest (as a percent)		99.90%	99.90%	99.90%
Common Units
Units issued		88,545,764	73,421,309	47,703,313
Units outstanding	8,864,222	88,545,764	73,421,309	47,703,313
Subordinated Units
Units issued			5,919,346	5,919,346
Units outstanding	5,919,346		5,919,346	5,919,346

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended	6 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2014
REVENUES:
Crude oil logistics	$2,111,143	$4,040,426
Water solutions	52,719	100,033
Liquids	539,753	1,014,910
Retail propane	68,358	146,260
Refined products and renewables	2,607,220	3,724,717
Other	1,333	2,794
Total Revenues	5,380,526	9,029,140
COST OF SALES:
Crude oil logistics	2,083,712	3,981,351
Water solutions	-9,439	1,134
Liquids	514,064	976,080
Retail propane	39,894	87,418
Refined products and renewables	2,550,851	3,665,164
Other	383	2,371
Total Cost of Sales	5,179,465	8,713,518
OPERATING COSTS AND EXPENSES:
Operating	101,553	169,421
General and administrative	41,639	69,512
Depreciation and amortization	50,099	89,474
Operating Income (Loss)	7,770	-12,785
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	3,697	6,262
Interest expense	-28,651	-49,145
Other, net	-617	-1,008
Loss before Income Taxes	-17,801	-56,676
INCOME TAX (PROVISION) BENEFIT	1,922	887
Net Loss	-15,879	-55,789
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056	-20,437
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-3,345	-3,410
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280	-79,636
Common Units
OTHER INCOME (EXPENSE):
NET LOSS ALLOCATED TO LIMITED PARTNERS	($30,280)	($75,623)
BASIC AND DILUTED LOSS PER COMMON UNIT (in dollars per unit)	($0.34)	($0.93)
BASIC AND DILUTED WEIGHTED AVERAGE UNITS OUTSTANDING:
COMMON UNITS OUTSTANDING (In shares)	88,331,653	81,267,742

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (Loss) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Condensed Consolidated Statements of Comprehensive Income (Loss)
Net loss	($15,879)	$43,146	$24,052	($932)	($17,508)	$22,341	$40,477	$10,082	($24,710)	($55,789)	($18,440)	$48,758	$48,190	$7,864
Other comprehensive income (loss)	-22			-5						163	-30	-260	-7	-25
Comprehensive loss	($15,901)			($937)						($55,626)	($18,470)	$48,498	$48,183	$7,839

Condensed_Consolidated_Stateme2

Condensed Consolidated Statement of Changes in Equity (USD $)	Total	Common Units	Accumulated Other Comprehensive Loss	Noncontrolling Interests	General Partner	Limited Partners	Limited Partners
In Thousands, except Share data, unless otherwise specified	USD ($)		USD ($)	USD ($)	USD ($)	Common Units	Subordinated Units
						USD ($)	USD ($)
BALANCES at Mar. 31, 2011	$47,353		$56		$72	$47,225
BALANCES (in units) at Mar. 31, 2011						10,933,568
Increase (Decrease) in Partnership Capital
Sales of units, net of issuance costs	75,289					75,289
Sales of units, net of issuance costs (in units)						4,025,000
Conversion of subordinated units to common units						-23,485	23,485
Conversion of subordinated units to common units (in units)						-5,919,346	5,919,346
Net income (loss)	7,864			-12	8	6,472	1,396
Other comprehensive income	-25		-25
BALANCES at Mar. 31, 2012	405,329		31	428	442	384,604	19,824
BALANCES (in units) at Mar. 31, 2012						23,296,253	5,919,346
Increase (Decrease) in Partnership Capital
Distributions	-71,682			-74	-1,778	-59,841	-9,989
Equity issued pursuant to incentive compensation plan	3,657					3,657
Equity issued pursuant to incentive compensation plan (in units)						156,802
Net income (loss)	48,190			250	2,917	41,705	3,318
Other comprehensive income	-7		-7
BALANCES at Mar. 31, 2013	889,418		24	5,740	-50,497	920,998	13,153
BALANCES (in units) at Mar. 31, 2013						47,703,313	5,919,346
Increase (Decrease) in Partnership Capital
Distributions	-145,930			-840	-9,703	-123,467	-11,920
Sales of units, net of issuance costs	650,155					650,155
Sales of units, net of issuance costs (in units)						22,560,848
Equity issued pursuant to incentive compensation plan	9,085					9,085
Equity issued pursuant to incentive compensation plan (in units)						296,269
Net income (loss)	48,758			1,103	14,148	32,712	795
Other comprehensive income	-260		-260
BALANCES at Mar. 31, 2014	1,531,853		-236	5,274	-45,287	1,570,074	2,028
BALANCES (in units) at Mar. 31, 2014						73,421,309	5,919,346
Increase (Decrease) in Partnership Capital
Distributions	-119,662			-8,654	-15,235	-89,025	-6,748
Contributions	395				395
Sales of units, net of issuance costs	370,446					370,446
Sales of units, net of issuance costs (in units)						8,767,100
Conversion of subordinated units to common units						-8,733	8,733
Conversion of subordinated units to common units (in units)						5,919,346	-5,919,346
Equity issued pursuant to incentive compensation plan	18,684					18,684
Equity issued pursuant to incentive compensation plan (in units)						438,009
Business combinations	568,740			568,740
Net income (loss)	-55,789			3,410	20,437	-75,623	-4,013
Other comprehensive income	163		163
BALANCES at Sep. 30, 2014	$2,314,830		($73)	$568,770	($39,690)	$1,785,823
BALANCES (in units) at Sep. 30, 2014						88,545,764

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
OPERATING ACTIVITIES:
Net loss	($55,789)	($18,440)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation and amortization, including debt issuance cost amortization	97,624	51,821
Non-cash equity-based compensation expense	11,758	6,762
Loss on disposal or impairment of assets	4,566	2,163
Provision for doubtful accounts	1,347	781
Commodity derivative (gain) loss	-38,496	17,881
Earnings of unconsolidated entities	-6,262
Distributions from unconsolidated entities	5,180
Other	-837	8
Changes in operating assets and liabilities, exclusive o f acquisitions:
Accounts receivable - trade	-358,497	-28,013
Accounts receivable - affiliates	-33,733	19,812
Inventories	-203,965	-226,727
Prepaid expenses and other assets	-56,109	-10,830
Accounts payable - trade	463,767	60,725
Accounts payable - affiliates	8,392	11,529
Accrued expenses and other liabilities	25,719	18,162
Advance payments received from customers	73,700	45,622
Net cash used in operating activities	-61,635	-48,744
INVESTING ACTIVITIES:
Purchases of long-lived assets	-82,851	-67,399
Acquisitions of businesses, including acquired working capital, net of cash acquired	-658,764	-392,605
Cash flows from commodity derivatives	4,327	-19,074
Proceeds from sales of assets	8,741	2,224
Investments in unconsolidated entities	-26,390
Distributions of capital from unconsolidated entities	4,649
Net cash used in investing activities	-750,288	-476,854
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,979,500	1,061,500
Payments on revolving credit facilities	-1,804,000	-893,000
Issuance of notes	400,000
Proceeds from borrowings on other long-term debt		880
Payments on other long-term debt	-4,175	-4,507
Debt issuance costs	-9,198	-2,218
Contributions	395	2,444
Distributions to owners	-111,008	-60,623
Distributions to noncontrolling interest partners	-8,654
Proceeds from sale of common units, net of offering costs	370,446	415,089
Net cash provided by financing activities	813,306	519,565
Net increase (decrease) in cash and cash equivalents	1,383	-6,033
Cash and cash equivalents, beginning of period	10,440	11,561
Cash and cash equivalents, end of period	$11,823	$5,528

Organization_and_Operations

Organization and Operations	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Organization and Operations
Organization and Operations	Note 1 — Organization and Operations	Note 1 — Nature of Operations and Organization
	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, 2014, our operations include:	NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership formed in September 2010 by several investors (“IEP Parties”). NGL Energy Holdings LLC serves as our general partner. At March 31, 2014, our operations include:
	·         Our crude oil logistics segment, the assets of which include owned and leased crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased and owned railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics segment purchases crude oil from producers and transports it for resale at owned and leased pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.	·                  A crude oil logistics business, the assets of which include crude oil storage terminals, pipeline injection stations, a fleet of trucks, a fleet of leased railcars, and a fleet of barges and towboats, and a 50% interest in a crude oil pipeline. Our crude oil logistics business purchases crude oil from producers and transports it for resale at pipeline injection points, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs.
	·         Our water solutions segment, the assets of which include water treatment and disposal facilities. Our water solutions segment generates revenues from the treatment and disposal of wastewater generated from crude oil and natural gas production, and from the sale of recycled water and recovered hydrocarbons.	·                  A water solutions business, the assets of which include water treatment and disposal facilities, a fleet of water trucks, and frac tanks. Our water solutions business generates revenues from the gathering, transportation, treatment, and disposal of wastewater generated from crude oil and natural gas production operations, and from the sale of recycled water and recovered hydrocarbons.
	·         Our liquids segment, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids segment purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, petrochemical plants, and other participants in the wholesale markets.	·                  Our liquids business, which supplies natural gas liquids to retailers, wholesalers, refiners, and petrochemical plants throughout the United States and in Canada, and which provides natural gas liquids terminaling services through its 22 terminals throughout the United States and railcar transportation services through its fleet of leased and owned railcars. Our liquids business purchases propane, butane, and other products from refiners, processing plants, producers, and other parties, and sells the product to retailers, refiners, and other participants in the wholesale markets.
	·         Our retail propane segment, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.	·                  Our retail propane business, which sells propane, distillates, and equipment and supplies to end users consisting of residential, agricultural, commercial, and industrial customers and to certain re-sellers in more than 20 states.
	·         Our refined products and renewables segment, which conducts gasoline, diesel, ethanol, and biodiesel marketing operations. We also own the 2.0% general partner interest and a 19.7% limited partner interest in TransMontaigne Partners L.P. (“TLP”), which conducts refined products terminaling operations. TLP also owns a 42.5% interest in Battleground Oil Specialty Terminal Company LLC (“BOSTCO”) and a 50% interest in Frontera Brownsville LLC (“Frontera”), which are entities that own refined products storage facilities.	We also operate a refined products marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities. We also operate a renewables business, which purchases ethanol primarily at production facilities and transports the ethanol for sale at various locations to refiners and blenders, and purchases biodiesel from production facilities in the Midwest and in Houston, Texas, and transports the product using leased railcars for sale to refiners and blenders. These businesses were acquired in our December 2013 acquisition of Gavilon, LLC (“Gavilon Energy”).
		Initial Public Offering
		On May 17, 2011, we completed our initial public offering (“IPO”). We sold a total of 4,025,000 common units in our IPO at $21.00 per unit. Our proceeds from the sale of 3,850,000 common units of $71.9 million, net of total offering costs of $9.0 million, were used to repay advances under our acquisition credit facility and for general partnership purposes. Proceeds from the sale of 175,000 common units ($3.4 million) from the underwriters’ exercise of their option to purchase additional common units from us were used to redeem 175,000 of the common units outstanding prior to our IPO. Upon the completion of our IPO and the underwriters’ exercise in full of their option to purchase additional common units from us and the redemption, we had outstanding 8,864,222 common units, 5,919,346 subordinated units, a 0.1% general partner interest, and incentive distribution rights (“IDRs”).
		Acquisitions Subsequent to Initial Public Offering
		Subsequent to our IPO, we significantly expanded our operations through a number of business combinations, including the following, among others:
		·                  In October 2011, we completed a business combination with E. Osterman Propane, Inc., its affiliated companies, and members of the Osterman family, whereby we acquired retail propane operations in the northeastern United States.
		·                  In November 2011, we completed a business combination with SemStream, L.P. (“SemStream”), whereby we acquired SemStream’s wholesale natural gas liquids supply and marketing operations and its 12 natural gas liquids terminals.
		·                  In January 2012, we completed a business combination with seven companies associated with Pacer Propane Holding, L.P., whereby we acquired retail propane operations, primarily in the western United States.
		·                  In February 2012, we completed a business combination with North American Propane, Inc., whereby we acquired retail propane and distillate operations in the northeastern United States.
		·                  In May 2012, we acquired the retail propane and distillate operations of Downeast Energy Corp (“Downeast”). These operations are primarily in the northeastern United States.
		·                  In June 2012, we completed a business combination with High Sierra Energy, LP and High Sierra Energy GP, LLC (collectively, “High Sierra”), whereby we acquired all of the ownership interests in High Sierra. High Sierra’s businesses include crude oil gathering, transportation and marketing; water treatment, disposal, and transportation; and natural gas liquids transportation and marketing.
		·                  In November 2012, we completed a business combination whereby we acquired Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”). The business of Pecos consists primarily of crude oil purchasing and logistics operations in Texas and New Mexico.
		·                  In December 2012, we completed a business combination whereby we acquired all of the membership interests in Third Coast Towing LLC (“Third Coast”). The business of Third Coast consists primarily of transporting crude oil via barge.
		·                  In July 2013, we completed a business combination whereby we acquired the assets of Crescent Terminals, LLC and the ownership interests in Cierra Marine, LP and its affiliated companies (collectively, “Crescent”), whereby we acquired four towboats, seven crude oil barges, and a crude oil terminal in South Texas.
		·                  In July 2013, we completed a business combination with High Roller Wells Big Lake SWD No. 1, Ltd. (“Big Lake”), whereby we acquired a water disposal facility in West Texas. We also entered into a development agreement that provides us the option to purchase disposal facilities that may be developed in the future. During March 2014, we purchased one additional facility under this agreement.
		·                  In August 2013, we completed a business combination whereby we acquired seven entities affiliated with Oilfield Water Lines LP (collectively, “OWL”). The businesses of OWL include water disposal operations and a water transportation business in Texas.
		·                  In September 2013, we completed a business combination with Coastal Plains Disposal #1, LLC (“Coastal”), in which we acquired the ownership interests in water disposal facilities in Texas and the right to purchase one additional facility, which we exercised in March 2014.
		·                  In December 2013, we acquired the ownership interests in Gavilon Energy. The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana and a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”), which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma. This pipeline became operational in February 2014. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids.

Significant_Accounting_Policie8

Significant Accounting Policies	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Significant Accounting Policies
Significant Accounting Policies	Note 2 — Significant Accounting Policies									Note 2 — Significant Accounting Policies
	Basis of Presentation									Basis of Presentation
	The unaudited condensed consolidated financial statements as of and for the three months and six months ended September 30, 2014 and 2013 include our accounts and those of our controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All significant intercompany transactions and account balances have been eliminated in consolidation. The unaudited condensed consolidated balance sheet at March 31, 2014 is derived from audited financial statements. We have made certain reclassifications to prior period financial statements to conform to classification methods used in fiscal year 2015. These reclassifications had no impact on previously reported amounts of equity or net income.									Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of the Partnership and its controlled subsidiaries. All significant intercompany transactions and account balances have been eliminated in consolidation.
	The accompanying unaudited condensed consolidated financial statements have been 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. 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 of only normal recurring items, unless otherwise disclosed herein. Accordingly, the unaudited condensed consolidated financial statements do not include all the 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 not misleading. These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the fiscal year ended March 31, 2014 included in our Annual Report on Form 10-K (the “Annual Report”). Due to the seasonal nature of our natural gas liquids operations and other factors, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.									We have made certain reclassifications to the prior period financial statements to conform with classification methods used in fiscal 2014. These reclassifications had no impact on previously-reported amounts of equity or net income. In addition, certain balances at March 31, 2013 were adjusted to reflect the final acquisition accounting for certain business combinations.
	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 reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period. Actual results could differ from those estimates.									The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period.
	Significant Accounting Policies									Critical estimates we make in the preparation of our consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations; the collectability of accounts receivable; the recoverability of inventories; useful lives and recoverability of property, plant and equipment and amortizable intangible assets; the impairment of goodwill; the fair value of derivative financial investments; and accruals for various commitments and contingencies, among others. Although we believe these estimates are reasonable, actual results could differ from those estimates.
	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
	Revenue Recognition									We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.
	We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, transportation, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Pursuant to terminaling services agreements with certain of our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Such measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.									We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our condensed consolidated statements of operations.									·                  Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.
	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 concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.									·                  Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at March 31, 2014 and 2013 (see Note 12). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.
	Fair Value Measurements									·                  Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at March 31, 2014 or 2013.
	We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.									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 the fair value measurement requires judgment, considering factors specific to the asset or liability.
	We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:									Derivative Financial Instruments
	·         Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.									We record our derivative financial instrument contracts at fair value in the consolidated balance sheets, with changes in the fair value of our commodity derivative instruments included in our consolidated statements of operations in cost of sales. Contracts that qualify for the normal purchase or sale exemption and are designated as such are not accounted for as derivatives at market value and, accordingly, are recorded when the delivery occurs.
	·         Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at September 30, 2014 and March 31, 2014 (see Note 11). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.									We have not designated any financial instruments as hedges for accounting purposes. All mark-to-market gains and losses on commodity derivative instruments that do not qualify as normal purchases or sales, whether cash transactions or non-cash mark-to-market adjustments, are reported within cost of sales in the consolidated statements of operations, regardless of whether the contract is physically or financially settled.
	·         Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at September 30, 2014 or March 31, 2014.									We utilize various commodity derivative financial instrument contracts to help reduce our exposure to variability in future commodity prices. We do not enter 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 the 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 market risk and credit risk. Market risk is the risk that the value of the portfolio will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from non-performance by suppliers, customers, or financial counterparties to a contract. We take an active role in managing and controlling market and credit risk and have established control procedures that we review on an ongoing basis. We monitor market risk through a variety of techniques and attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures.
	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 the fair value measurement requires judgment, considering factors specific to the asset or liability.									Revenue Recognition
	Supplemental Cash Flow Information									We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for the wastewater disposal business are recognized upon receipt of the wastewater at our disposal facilities.
	Supplemental cash flow information is as follows:									We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in the consolidated statements of operations.
		Three Months Ended				Six Months Ended				We enter into certain contracts whereby we agree to purchase product from a counterparty and to sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.
		September 30,				September 30,
		2014		2013		2014		2013		Cost of Sales
		(in thousands)
	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	10,445	$	8,423	$	36,429	$	16,908	We include in cost of sales all costs we incur to acquire products, including the costs of purchasing, terminaling, and transporting inventory prior to delivery to our customers. Cost of sales does not include any depreciation of our property, plant and equipment. Cost of sales does include amortization of certain contract-based intangible assets of $6.2 million, $5.3 million, and $0.8 million during the years ended March 31, 2014, 2013, and 2012, respectively.
	Income taxes paid	$	1,241	$	369	$	2,246	$	650
										Depreciation and Amortization
	Value of common units issued in business combinations	$	—	$	80,619	$	—	$	80,619
										Depreciation and amortization in the consolidated statements of operations includes all depreciation of our property, plant and equipment and amortization of intangible assets other than debt issuance costs, for which the amortization is recorded to interest expense, and certain contract-based intangible assets, for which the amortization is recorded to cost of sales.
	Cash flows from settlements of commodity derivative instruments are classified as cash flows from investing activities in the condensed consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in the reconciliation of net loss to net cash used in operating activities.
										Cash and Cash Equivalents
	Inventories
										Cash and cash equivalents include cash on hand, demand and time deposits, and funds invested in highly liquid instruments with maturities of three months or less at the date of purchase. At times, certain account balances may exceed federally insured limits.
	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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
										Supplemental cash flow information is as follows:
	Inventories consist of the following:
											Year Ended March 31,
		September 30,		March 31,							2014			2013			2012
		2014		2014							(in thousands)
		(in thousands)								Interest paid, exclusive of debt issuance costs and letter of credit fees	$	31,827		$	27,384		$	4,966
	Crude oil	$	136,722	$	156,473					Income taxes paid	$	1,639		$	1,027		$	430
	Natural gas liquids —
	Propane	207,694		85,159						Cash flows from commodity derivative instruments are classified as cash flows from investing activities in the consolidated statements of cash flows.
	Butane	84,822		15,106
	Other	27,091		3,945						Accounts Receivable and Concentration of Credit Risk
	Refined products —
	Gasoline	219,111		15,597						We operate in the United States and Canada. We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions. The allowance for doubtful accounts is based on our assessment of the collectability of customer accounts, which assessment considers the overall creditworthiness of customers and any specific disputes. Accounts receivable are considered past due or delinquent based on contractual terms. We write off accounts receivable against the allowance for doubtful accounts when collection efforts have been exhausted.
	Diesel	214,567		7,298
	Other	3,675		314						We execute netting agreements with certain customers to mitigate our credit risk. Receivables and payables are reflected at a net balance to the extent a netting agreement is in place and we intend to settle on a net basis.
	Renewables	36,517		11,778
	Other	11,390		14,490						Our accounts receivable consist of the following:
	Total	$	941,589	$	310,160
											March 31, 2014						March 31, 2013
	Investments in Unconsolidated Entities																Gross
											Gross			Allowance for			Receivable			Allowance for
	In December 2013, as part of our acquisition of Gavilon, LLC (“Gavilon Energy”), we acquired a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”) and an 11% interest in a limited liability company that owns an ethanol production facility. In June 2014, we acquired an interest in a limited liability company that operates a water supply business. On July 1, 2014, as part of our acquisition of TransMontaigne Inc. (“TransMontaigne”), we acquired TLP, which owns a 42.5% interest in BOSTCO and a 50% interest in Frontera. We account for these investments 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 book value of the net assets of the investment entity.									Segment	Receivable			Doubtful Accounts			(Note 2)			Doubtful Accounts
											(in thousands)
	Our investments in unconsolidated entities consist of the following:									Crude oil logistics	$	411,090		$	105		$	360,589		$	11
										Water solutions	25,700			405			9,618			29
		September 30,		March 31,						Liquids	192,529			617			144,267			76
		2014		2014						Retail propane	75,606			1,667			49,233			1,644
		(in thousands)								Refined products	105,670			—			—			—
	Glass Mountain (1)	$	189,847	$	181,488					Renewables	54,466			—			—			—
Ethanol production facility	9,361		8,333						Other	38,665			28			810			—
Water supply company	15,026		—							$	903,726		$	2,822		$	564,517		$	1,760
BOSTCO (2)	244,092		—
Frontera	24,318		—						Changes in the allowance for doubtful accounts are as follows:
Total	$	482,644	$	189,821
										Year Ended March 31,
										2014			2013			2012
(1)     When we acquired Gavilon we recorded the investment in Glass Mountain at fair value. The fair value of our investment in Glass Mountain exceeds our share of the historical net book value of Glass Mountain’s net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.										(in thousands)
									Allowance for doubtful accounts, beginning of period	$	1,760		$	818		$	161
(2)     When we acquired TransMontaigne, we recorded the investment in BOSTCO at fair value. The fair value of our investment in BOSTCO exceeds our share of the historical net book value of BOSTCO’s net assets by approximately $24 million.									Provision for doubtful accounts	2,172			1,315			1,049
									Write off of uncollectible accounts	(1,110		)	(373		)	(392		)
Accrued Expenses and Other Payables									Allowance for doubtful accounts, end of period	$	2,822		$	1,760		$	818
Accrued expenses and other payables consist of the following:									For the year ended March 31, 2014, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. For the year ended March 31, 2013, sales of crude oil and natural gas liquids to our largest customer represented 10% of our consolidated total revenues. At March 31, 2013, one customer of our crude oil logistics segment represented 10% of our consolidated accounts receivable balance.
	September 30,		March 31,						Inventories
	2014		2014
	(in thousands)								We value our inventory 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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
Accrued compensation and benefits	$	49,146	$	45,006
Derivative liabilities	39,023		42,214						Inventories consist of the following:
Product exchange liabilities	43,185		3,719
Accrued interest	23,945		18,668							March 31,
Income and other tax liabilities	38,255		13,421							2014			2013
Other	24,928		18,662							(in thousands)
Total	$	218,482	$	141,690					Crude oil	$	156,473		$	46,156
									Natural gas liquids —
Business Combination Measurement Period									Propane	85,159			45,428
									Butane and other	19,051			24,090
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 fair value of the assets acquired and liabilities assumed in a business combination. As described 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 described in Note 4, we made certain adjustments during the six months ended September 30, 2014 to our estimates of the acquisition-date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2014.									Refined products	23,209			—
									Renewables	11,778			—
Noncontrolling Interests									Other	14,490			11,221
										$	310,160		$	126,895
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’ share of these entities.
									Investments in Unconsolidated Entities
On July 1, 2014, as part of our acquisition of TransMontaigne, we acquired a 19.7% limited partner interest in TLP. We have attributed net earnings allocable to TLP’s limited partners to the controlling and noncontrolling interests based on the relative ownership interests in TLP as well as including certain adjustments related to our acquisition accounting. Net earnings allocable to TLP’s limited partners are net of the earnings allocable to TLP’s general partner interest. The earnings allocable to TLP’s general partner interest include the distributions of available cash (as defined by TLP’s partnership agreement) attributable to the period to TLP’s general partner interest and incentive distribution rights, net of adjustments for TLP’s general partner’s share of undistributed earnings. Undistributed earnings are allocated to TLP’s limited partners and TLP’s general partner interest based on their respective sharing of earnings or losses specified in TLP’s partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively.
									As part of the December 2013 acquisition of Gavilon Energy, we acquired a 50% interest in Glass Mountain and an 11% interest in a limited liability company that owns an ethanol production facility. We account for these investments under the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheet; instead, our ownership interests are reported within “Investments in Unconsolidated Entities” on our consolidated balance sheet. We record our share of any income or loss generated by these entities as an increase to our equity method investments, and record any distributions we receive from these entities as reductions to our equity method investments.
									Accrued Expenses and Other Payables
									Accrued expenses and other payables consist of the following:
										March 31,
													2013
										2014			(Note 4)
										(in thousands)
									Accrued compensation and benefits	$	45,006		$	27,252
									Derivative liabilities	42,214			12,701
									Income and other tax liabilities	13,421			22,659
									Product exchange liabilities	3,719			6,741
									Other	37,330			16,253
										$	141,690		$	85,606
									Property, Plant and Equipment
									We record property, plant and equipment at cost, less accumulated depreciation. Acquisitions and improvements are capitalized, and maintenance and repairs are expensed as incurred. As we dispose of assets, we remove the cost and related accumulated depreciation from the accounts, and any resulting gain or loss is included in other income. We compute depreciation expense using the straight-line method over the estimated useful lives of the assets (see Note 5).
									We evaluate the carrying value of our property, plant and equipment for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group.
									Intangible Assets
									Our intangible assets include contracts and arrangements acquired in business combinations, including lease agreements, customer relationships, covenants not to compete, and trade names. In addition, we capitalize certain debt issuance costs incurred in our long-term debt arrangements. We amortize our intangible assets on a straight-line basis over the assets’ estimated useful lives (see Note 7). We amortize debt issuance costs over the terms of the related debt on a method that approximates the effective interest method.
									We evaluate the carrying value of our amortizable intangible assets for potential impairment when events and circumstances warrant such a review. A long-lived asset group is considered impaired when the anticipated undiscounted future cash flows from the use and eventual disposition of the asset group is lower than its carrying value. In that event, we recognize a loss equal to the amount by which the carrying value exceeds the fair value of the asset group. When we cease to use an acquired trade name, we test the trade name for impairment using the “relief from royalty” method and we begin amortizing the trade name over its estimated useful life as a defensive asset.
									Goodwill
									Goodwill represents the excess of cost over the fair value of net assets of acquired businesses. Business combinations are accounted for using the “acquisition method” (see Note 4). We expect that substantially all of our goodwill at March 31, 2014 is deductible for income tax purposes.
									Goodwill and intangible assets determined to have an indefinite useful life are not amortized, but instead are evaluated for impairment periodically. We evaluate goodwill and indefinite-lived intangible assets for impairment annually, or more often if events or circumstances indicate that the assets might be impaired. We perform the annual evaluation at January 1 of each year.
									To perform this assessment, we consider qualitative factors to determine whether it is more likely than not that the fair value of each reporting unit exceeds its carrying amount. If we conclude that it is more likely than not that the fair value of a reporting unit exceeds its carrying amount, we perform the following two-step goodwill impairment test:
									·                  In the first step of the goodwill impairment test, we compare the fair value of the reporting unit with its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered impaired. If the carrying amount of a reporting unit exceeds its fair value, we perform the second step of the goodwill impairment test to measure the amount of impairment loss, if any.
									·                  In the second step of the goodwill impairment test, we compare the implied fair value of reporting unit goodwill with the carrying amount of that goodwill. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to that excess.
									Estimates and assumptions used to perform the impairment evaluation are inherently uncertain and can significantly affect the outcome of the analysis. The estimates and assumptions we used in the annual assessment for impairment of goodwill included market participant considerations and future forecasted operating results. Changes in operating results and other assumptions could materially affect these estimates. Based on our assessment of qualitative factors, we determined that the two-step impairment test was not required. Accordingly, we did not record any goodwill impairments during the years ended March 31, 2014, 2013, and 2012.
									Product Exchanges
									Quantities of products receivable or returnable under exchange agreements are reported within prepaid expenses and other current assets or within accrued expenses and other payables on the consolidated balance sheets. We estimate the value of product exchange assets and liabilities based on the weighted-average cost basis of the inventory we have delivered or will deliver on the exchange, plus or minus location differentials.
									Advance Payments Received from Customers
									We record customer advances on product purchases as a liability on the consolidated balance sheets.
									Noncontrolling Interests
									We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our consolidated statements of operations represents the other owners’ share of the net income (loss) of these entities.
									Water Facility Development Agreement
									In connection with one of our business combinations, we entered into a development agreement whereby we may acquire additional water disposal facilities in Texas. Under this agreement, the other party (the “Developer”) may develop facilities in a designated area. We then have the option to operate the facility for a period of up to 90 days, during which time we may elect to purchase the facility. If we elect to purchase the facility, the Developer may choose one of two options specified in the agreement for the calculation of the purchase price.
									During the period between which we have begun operating the facility and we have decided whether to purchase the facility, we are entitled to a fee for operating the facility, which is forfeitable if we elect not to purchase the facility. We recognize revenue for these operator fees once they cease to be forfeitable. When we elect to purchase a facility, we account for the transaction as a business combination.
									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 to obtain the information necessary to identify and measure the value of the assets acquired and liabilities assumed in a business combination. As described in Note 4, certain of our acquisitions during the year ended March 31, 2014 are still within this measurement period, and as a result, the acquisition-date fair values we have recorded for the acquired assets and assumed liabilities are subject to change.
									Also as described in Note 4, we made certain adjustments during the year ended March 31, 2014 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2013. We retrospectively adjusted the March 31, 2013 consolidated balance sheet for these adjustments. Due to the immateriality of these adjustments, we did not retrospectively adjust the consolidated statement of operations for the year ended March 31, 2013 for these measurement period adjustments.
									Discontinued Operations
									In April 2014, the Financial Accounting Standards Board issued an Accounting Standards Update that changes the criteria for reporting discontinued operations. Under the new standard, a disposal of part of an entity is not classified as a discontinued operation unless the disposal represents a strategic shift that will have a major effect on an entity’s operations and financial results. We adopted the new standard during the fiscal year ended March 31, 2014.
									As described in Note 14, during the year ended March 31, 2014, we sold our compressor leasing business and wound down our natural gas marketing business. These actions do not represent a strategic shift that had a major effect on our operations, and do not meet the criteria under the new accounting standard for these businesses to be reported as discontinued operations.

Recovered_Sheet1

Earnings Per Unit	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Earnings Per Unit
Earnings Per Unit	Note 3 — Earnings Per Unit													Note 3 — Earnings per Unit
	Our earnings per common unit were computed as follows:													Our earnings per common and subordinated unit were computed as follows:
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands, except unit and per unit amounts)
		(in thousands, except unit and per unit amounts)
	Net loss attributable to parent equity	$	(19,224	)	$	(941	)	$	(59,199	)	$	(18,574	)	Income attributable to parent equity	$	47,655		$	47,940		$	7,876
	Less: net income allocated to general partner (1)	(11,056		)	(2,451		)	(20,437		)	(4,139		)	Income allocated to general partner (1)	(14,148		)	(2,917		)	(8		)
	Net loss allocated to subordinated unitholders (2)	—			562			4,013			3,076			Income attributable to limited partners	$	33,507		$	45,023		$	7,868
	Net loss allocated to common unitholders	$	(30,280	)	$	(2,830	)	$	(75,623	)	$	(19,637	)
														Income allocated to:
	Weighted average common units outstanding	88,331,653			58,909,389			81,267,742			53,336,969			Common unitholders	$	31,614		$	39,517		$	4,859
														Subordinated unitholders	$	1,893		$	5,506		$	3,009
	Loss per common unit - basic and diluted	$	(0.34	)	$	(0.05	)	$	(0.93	)	$	(0.37	)
														Weighted average common units outstanding	61,970,471			41,353,574			15,169,983
														Weighted average subordinated units outstanding	5,919,346			5,919,346			5,175,384
	(1)     The net income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are described in Note 10.
	(2)     All outstanding subordinated units converted to common units in August 2014. Since the subordinated units did not share in the distribution of cash generated during the three months ended September 30, 2014, we did not allocate any earnings or loss during this period to the subordinated unitholders. During the three months ended June 30, 2014 and the six months ended September 30, 2013, 5,919,346 subordinated units were outstanding. The loss per subordinated unit was $(0.68) for the three months ended June 30, 2014, $(0.09) for the three months ended September 30, 2013, and $(0.52) for the six months ended September 30, 2013.													Income per common unit - basic and diluted	$	0.51		$	0.96		$	0.32
	The restricted units described in Note 10 were antidilutive during the three months and six months ended September 30, 2014 and 2013, but could impact earnings per unit in future periods.													Income per subordinated unit - basic and diluted	$	0.32		$	0.93		$	0.58
														(1)         The income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights (“IDRs”), which are described in Note 11.
														The restricted units described in Note 11 were antidilutive for the years ended March 31, 2014, 2013, and 2012.

Acquisitions1

Acquisitions	6 Months Ended										12 Months Ended
	Sep. 30, 2014										Mar. 31, 2014
Acquisitions
Acquisitions	Note 4 — Acquisitions										Note 4 — Acquisitions
	Year Ending March 31, 2015										Year Ended March 31, 2014
	TransMontaigne Inc.										Gavilon Energy
	On July 1, 2014, we acquired TransMontaigne for $174.2 million of cash, net of cash acquired. As part of this transaction, we also purchased $380.4 million of inventory from the previous owner of TransMontaigne (including $346.9 million paid at closing and $33.5 million subsequently paid as the working capital settlement process progressed). The operations of TransMontaigne include the marketing of refined products and crude oil. As part of this transaction, we acquired the 2.0% general partner interest, the incentive distribution rights, and a 19.7% limited partner interest in TLP, and assumed certain terminaling service agreements with TLP from an affiliate of the previous owner of TransMontaigne. The acquisition agreement contemplates a post-closing adjustment to the purchase price for certain working capital items. We estimate that we will pay an additional $27.5 million once the working capital settlement process has been completed.										On December 2, 2013, we completed a business combination in which we acquired Gavilon Energy. We paid $832.4 million of cash, net of cash acquired, in exchange for these assets and operations. The acquisition agreement also contemplates a post-closing adjustment to the purchase price for certain working capital items. We incurred and charged to general and administrative expense $5.3 million of costs during the year ended March 31, 2014 related to the acquisition of Gavilon Energy.
	We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in this business combination. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2015. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):										The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana and a 50% interest in Glass Mountain, which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma. This pipeline became operational in February 2014. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids.
	Cash and cash equivalents	$	1,469								We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in the acquisition of Gavilon Energy. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending September 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	Accounts receivable - trade	197,349
	Accounts receivable - affiliates	528									Accounts receivable - trade	$	349,529
	Inventories	426,913									Accounts receivable - affiliates	2,564
	Prepaid expenses and other current assets	15,373									Inventories	107,430
	Property, plant and equipment:										Prepaid expenses and other current assets	68,322
	Refined products terminal assets (20 years)	418,405									Property, plant and equipment:
	Buildings and leasehold improvements (20 years)	10,339									Crude oil tanks and related equipment (3—40 years)	77,429
	Crude oil tanks and related equipment (20 years)	28,666									Vehicles (3 years)	791
	Vehicles	1,565									Information technology equipment (3—7 years)	4,046
	Land	56,095									Buildings and leasehold improvements (3—40 years)	7,716
	Information technology equipment	7,851									Land	6,427
	Other	12,592									Linefill and tank bottoms	15,230
	Construction in progress	4,487									Other (7 years)	170
	Goodwill (1)	29,118									Construction in process	7,190
	Intangible assets:										Goodwill	359,169
	Customer relationships (7 years)	50,000									Intangible assets:
	Pipeline capacity rights (30 years)	87,000									Customer relationships (10—20 years)	101,600
	Trade names (indefinite life)	5,000									Lease agreements (1—5 years)	8,700
	Equity method investments	250,000									Investments in unconsolidated entities	178,000
	Other noncurrent assets	3,911									Other noncurrent assets	9,918
	Accounts payable - trade	(140,597		)							Accounts payable - trade	(342,792		)
	Accounts payable - affiliates	(69		)							Accounts payable - affiliates	(2,585		)
	Accrued expenses and other payables	(73,565		)							Accrued expenses and other payables	(70,999		)
	Advance payments received from customers	(1,919		)							Advance payments received from customers	(10,667		)
	Long-term debt	(234,000		)							Other noncurrent liabilities	(44,740		)
	Other noncurrent liabilities	(34,856		)							Fair value of net assets acquired	$	832,448
	Noncontrolling interests	(567,120		)
	Fair value of net assets acquired	$	554,535								Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership, the opportunity to use the acquired business as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
											Our preliminary estimate of the fair value of investments in unconsolidated subsidiaries exceeds our share of the historical net book value of these subsidiaries’ net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.
	(1)     Included in the refined products and renewables segment.
											The acquisition method of accounting requires that executory contracts that are at unfavorable terms relative to current market conditions at the acquisition date be recorded as assets or liabilities in the acquisition accounting. Since certain crude oil storage lease commitments were at unfavorable terms relative to current market conditions, we recorded a liability of $12.9 million related to these lease commitments in the acquisition accounting, and we amortized $2.9 million of this balance through cost of sales during the period from the acquisition date through March 31, 2014. We will amortize the remainder of this liability over the term of the leases. The future amortization of this liability is shown below (in thousands):
	Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership, the opportunity to use the acquired business as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
											Year Ending March 31,
	The intangible asset for pipeline capacity rights relates to capacity allocations on a third-party refined products pipeline. Demand for use of this pipeline exceeds the pipeline’s capacity, and the limited capacity is allocated based on a shipper’s historical shipment volumes.										2015	$	6,500
											2016	3,260
	The fair value of the noncontrolling interests was calculated by multiplying the closing price of TLP’s common units on the acquisition date by the number of TLP common units held by parties other than us.										2017	300
	We recorded in the acquisition accounting a liability of $2.5 million related to certain crude oil contracts with terms that were unfavorable at current market conditions. We amortized this balance to cost of sales during the three months ended September 30, 2014.
											As described in Note 14, on March 31, 2014, we assigned all of the storage and transportation contracts of the natural gas marketing business to a third party.  Since these contracts were at unfavorable terms relative to current market conditions, we paid $44.8 million to assign these contracts. We recorded a liability of $50.8 million related to these storage and transportation contracts in the acquisition accounting, and we amortized $6.0 million of this balance through cost of sales during the period from the acquisition date through the date we assigned the contracts.
	Employees of TransMontaigne participate in a plan whereby they are entitled to certain termination benefits in the event of a change in control of TransMontaigne and a subsequent change in job status. We recorded expense of $2.7 million during the three months ended September 30, 2014 related to these termination benefits, and we may record additional expense in future quarters as we continue our integration efforts.
											We recorded $3.2 million of employee severance expense during the year ended March 31, 2014 as a result of personnel changes subsequent to the acquisition of Gavilon Energy. In addition, certain personnel who were employees of Gavilon Energy are entitled to a bonus, half of which was payable upon successful completion of the business combination and the remainder of which is payable in December 2014. We are recording this as compensation expense over the vesting period. We recorded expense of $5.0 million during the year ended March 31, 2014 related to these bonuses, and we expect to record an additional expense of $6.6 million during the year ending March 31, 2015.
	The operations of TransMontaigne have been included in our condensed consolidated statements of operations since TransMontaigne was acquired on July 1, 2014. Our condensed consolidated statements of operations for the three months and six months ended September 30, 2014 include revenues of $1.1 billion and an operating loss of $0.3 million that were generated by the operations of TransMontaigne. We have not provided supplemental pro forma financial information as though the business combination had occurred on April 1, 2013. The previous owner of TransMontaigne conducted trading operations, whereas we strive to generate reliable and predictable cash flows. Because of the difference in strategies between the pre-acquisition and post-acquisition periods, the pre-acquisition operations of TransMontaigne have limited importance as an indicator of post-acquisition results.
											The operations of Gavilon Energy have been included in our consolidated statement of operations since Gavilon Energy was acquired on December 2, 2013. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $2.9 billion and operating income of $11.0 million that were generated by the operations of Gavilon Energy.
	On July 10, 2014, we submitted a nonbinding proposal to the conflicts committee of the board of directors of TLP’s general partner. Under this proposal, each outstanding unit of TLP would be exchanged for one of our common units. On August 15, 2014, we and TLP’s general partner terminated discussions regarding our previously submitted nonbinding proposal to acquire the outstanding common units of TLP.
											Oilfield Water Lines, LP
	Water Solutions Facilities
											On August 2, 2013, we completed a business combination with entities affiliated with OWL, whereby we acquired water disposal and transportation assets in Texas. We issued 2,463,287 common units, valued at $68.6 million, and paid $167.7 million of cash, net of cash acquired, in exchange for OWL. The acquisition agreements included a provision whereby the purchase price could have been increased if certain performance targets were achieved in the six months following the acquisition. These performance targets were not achieved, and therefore no increase to the purchase price was warranted. The acquisition agreements also contemplate a post-closing payment for certain working capital items. We incurred and charged to general and administrative expense $0.8 million of costs related to the OWL acquisition during the year ended March 31, 2014.
	As described below, we are party to a development agreement that provides us a right to purchase water disposal facilities developed by the other party to the agreement. During the six months ended September 30, 2014, we purchased four water disposal facilities under this development agreement. We also purchased a 75% interest in one additional water disposal facility in July 2014 from a different seller. On a combined basis, we paid $82.9 million of cash for these five water disposal facilities.
											We have completed the process of identifying and determining the fair value of the long-lived assets acquired in the acquisition of OWL. We have not yet finalized any post-closing payment for certain working capital items, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these business combinations. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2015. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
											Accounts receivable - trade	$	7,268
	Accounts receivable - trade	$	939								Inventories	154
	Inventories	253									Prepaid expenses and other current assets	402
	Prepaid expenses and other current assets	62									Property, plant and equipment:
	Property, plant and equipment:										Land	710
	Water treatment facilities and equipment (5–40 years)	23,066									Water treatment facilities and equipment (3—30 years)	23,173
	Buildings and leasehold improvements (3–7 years)	2,599									Vehicles (5—10 years)	8,157
	Land	1,010									Buildings and leasehold improvements (7—30 years)	2,198
	Other (7 years)	33									Other (3—5 years)	53
Goodwill	57,777									Intangible assets:
Other noncurrent assets	50									Customer relationships (10 years)	110,000
Accounts payable - trade	(58		)							Non-compete agreements (2.5 years)	2,000
Accrued expenses and other payables	(1,092		)							Goodwill	89,699
Other noncurrent liabilities	(149		)							Accounts payable - trade	(6,469		)
Noncontrolling interest	(1,620		)							Accrued expenses and other payables	(992		)
Fair value of net assets acquired	$	82,870								Other noncurrent liabilities	(64		)
										Fair value of net assets acquired	$	236,289
Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entity and the Partnership and the opportunity to use the acquired business as a platform for growth. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Consideration paid consists of the following (in thousands):
The operations of these water disposal facilities have been included in our condensed consolidated statement of operations since their acquisition date. Our condensed consolidated statement of operations for the quarter ended September 30, 2014 includes revenues of $7.1 million and operating income of $1.5 million that were generated by the operations of these water disposal facilities.
										Cash paid, net of cash acquired	$	167,732
Retail Propane Acquisitions										Value of common units issued	68,557
										Total consideration paid	$	236,289
During the six months ended September 30, 2014, we completed three acquisitions of retail propane businesses. On a combined basis, we paid $6.4 million of cash to acquire these assets and operations. The agreements for these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result, the estimates of fair value reflected at September 30, 2014 are subject to change.
										The customer relationships were valued using a variation of the income approach known as the excess earnings method. This methodology consists of deriving relevant cash flows to the underlying asset, and then deducting appropriate returns for other assets contributing to the generation of the relevant cash flows. This valuation methodology requires estimates of customer retention, which were based on our understanding of the level of competition in the region in which the assets operate. Our estimates of customer retention are also relevant to the determination of the estimated useful lives of the assets.
Water Supply Company
										Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
On June 9, 2014, we paid cash of $15.0 million in exchange for an interest in a water supply company operating in the DJ Basin. We account for this investment using the equity method of accounting.
										The operations of OWL have been included in our consolidated statement of operations since OWL was acquired on August 2, 2013. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $26.2 million and operating income of $0.9 million that was generated by the operations of OWL.
Year Ended March 31, 2014
										Other Water Solutions Acquisitions
As described in Note 2, pursuant to GAAP, an entity is allowed a reasonable period of time to obtain the information necessary to identify and measure the fair value of the assets acquired and liabilities assumed in a business combination. The business combinations for which this measurement period was still open as of March 31, 2014 are summarized below.
										During the year ended March 31, 2014, we completed four separate acquisitions of businesses to expand our water solutions operations in Texas. On a combined basis, we issued 222,381 common units, valued at $6.8 million, and paid $178.9 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. Our consolidated statement of operations for the year ended March 31, 2014 includes revenues of $20.6 million and operating income of $7.1 million that was generated by the operations of these acquisitions. We incurred and charged to general and administrative expense $0.4 million of costs related to these acquisitions during the year ended March 31, 2014.
Gavilon Energy
										We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these four business combinations. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending September 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
On December 2, 2013, we completed a business combination in which we acquired Gavilon Energy. We paid $832.4 million of cash, net of cash acquired, in exchange for these assets and operations. The acquisition agreement also contemplates a post-closing adjustment to the purchase price for certain working capital items.
										Accounts receivable - trade	$	2,391
The assets of Gavilon Energy include crude oil terminals in Oklahoma, Texas, and Louisiana, a 50% interest in Glass Mountain, which owns a crude oil pipeline that originates in western Oklahoma and terminates in Cushing, Oklahoma, and an 11% interest in an ethanol production facility in the Midwest. The operations of Gavilon Energy include the marketing of crude oil, refined products, ethanol, biodiesel, and natural gas liquids and owned and leased crude oil storage in Cushing, Oklahoma.										Inventories	390
										Prepaid expenses and other current assets	61
During the three months ended September 30, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for this acquisition:										Property, plant and equipment:
										Land	419
				Estimated at						Vehicles (5—10 years)	90
				at						Water treatment facilities and equipment (3—30 years)	24,933
				March 31,						Buildings and leasehold improvements (7—30 years)	3,036
	Final			2014			Change			Other (3—5 years)	13
	(in thousands)									Intangible assets:
Accounts receivable - trade	$	326,484		$	349,529		$	(23,045	)	Customer relationships (8—10 years)	72,000
Accounts receivable - affiliates	2,564			2,564			—			Trade names (indefinite life)	3,325
Inventories	107,430			107,430			—			Non-compete agreements (3 years)	260
Prepaid expenses and other current assets	68,322			68,322			—			Water facility development agreement (5 years)	14,000
Property, plant and equipment:										Water facility option agreement	2,500
Vehicles (3 years)	327			791			(464		)	Goodwill	63,031
Crude oil tanks and related equipment (3–40 years)	83,797			77,429			6,368			Accounts payable - trade	(382		)
Information technology equipment (3–7 years)	4,049			4,046			3			Accrued expenses and other payables	(300		)
Buildings and leasehold improvements (3–40 years)	7,817			7,716			101			Other noncurrent liabilities	(114		)
Land	6,427			6,427			—			Fair value of net assets acquired	$	185,653
Tank bottoms	16,930			15,230			1,700
Other (7 years)	162			170			(8		)	Consideration paid consists of the following (in thousands):
Construction in progress	7,180			7,190			(10		)
Goodwill (1)	342,769			359,169			(16,400		)	Cash paid, net of cash acquired	$	178,867
Intangible assets:										Value of common units issued	6,786
Customer relationships (10–20 years)	107,950			101,600			6,350			Total consideration paid	$	185,653
Lease agreements (1–5 years)	8,700			8,700			—
Pipeline capacity rights (30 years)	7,800			—			7,800			Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Investments in unconsolidated entities	183,000			178,000			5,000
Other noncurrent assets	2,287			9,918			(7,631		)	As part of one of these business combinations, we entered into an option agreement with the seller of the business whereby we had the option to purchase a salt water disposal facility that was under construction. We recorded an intangible asset of $2.5 million at the acquisition date related to this option agreement. On March 1, 2014, we purchased the saltwater disposal facility for additional cash consideration of $3.7 million. The assets associated with this facility are included in the data in the table above.
Accounts payable - trade	(342,792		)	(342,792		)	—
Accounts payable - affiliates	(2,585		)	(2,585		)	—			As part of one of these business combinations, we entered into a development agreement that provides us a first right of refusal to purchase disposal facilities that may be developed by the seller within a defined area in the Eagle Ford Basin through June 2018. On March 1, 2014, we purchased our first disposal facility pursuant to the development agreement for $21.0 million. The assets associated with this facility are included in the data in the table above. In addition, we have exercised our option to operate, for evaluation purposes, three additional disposal facilities developed by the seller. Pending the results of our evaluation, we have the right to purchase any or all of these facilities within the 90-day evaluation period.
Accrued expenses and other payables	(49,447		)	(70,999		)	21,552
Advance payments received from customers	(10,667		)	(10,667		)	—			Crude Oil Logistics Acquisitions
Other noncurrent liabilities	(46,056		)	(44,740		)	(1,316		)
Fair value of net assets acquired	$	832,448		$	832,448		$	—		During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our crude oil logistics business in Texas and Oklahoma. On a combined basis, we issued 175,211 common units, valued at $5.3 million, and paid $67.8 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. The agreement for the acquisition of one of these businesses contemplates a post-closing payment for certain working capital items. We incurred and charged to general and administrative expense during the year ended March 31, 2014 $0.1 million of costs related to these acquisitions.
										We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these two business combinations. The estimates of fair value reflected at March 31, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending June 30, 2014. We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
(1)     Primarily included in the crude oil logistics segment.
										Accounts receivable - trade	$	1,235
We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.										Inventories	1,021
										Prepaid expenses and other current assets	54
The acquisition method of accounting requires that executory contracts that are at unfavorable terms relative to current market conditions at the acquisition date be recorded as assets or liabilities in the acquisition accounting. Since certain crude oil storage lease commitments were at unfavorable terms relative to current market conditions, we recorded a liability of $15.9 million related to these lease commitments in the acquisition accounting, and we amortized $5.0 million of this balance through cost of sales during the six months ended September 30, 2014. We will amortize the remainder of this liability over the term of the leases. The future amortization of this liability is shown below (in thousands):										Property, plant and equipment:
										Vehicles (5—10 years)	2,977
Year Ending March 31,										Buildings and leasehold improvements (5—30 years)	280
2015 (six months)	$	3,670								Crude oil tanks and related equipment (2—30 years)	3,462
2016	4,040									Barges and towboats (20 years)	20,065
2017	360									Other (3—5 years)	53
										Intangible assets:
										Customer relationships (3 years)	6,300
Certain personnel who were employees of Gavilon Energy are entitled to a bonus, half of which was payable upon successful completion of the business combination and the remainder of which is payable in December 2014. We are recording this as compensation expense over the vesting period. We recorded expense of $5.2 million during the six months ended September 30, 2014 related to these bonuses, and we expect to record an additional expense of $1.6 million during the quarter ending December 31, 2014.										Non-compete agreements (3 years)	35
										Trade names (indefinite life)	530
Oilfield Water Lines, LP										Goodwill	37,867
										Accounts payable - trade	(665		)
On August 2, 2013, we completed a business combination with entities affiliated with Oilfield Water Lines LP (collectively, “OWL”), whereby we acquired water disposal and transportation assets in Texas. We issued 2,463,287 common units, valued at $68.6 million, and paid $167.7 million of cash, net of cash acquired, in exchange for OWL. During the three months ended June 30, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed in the acquisition of OWL:										Accrued expenses and other payables	(124		)
										Fair value of net assets acquired	$	73,090
				Estimated
				at						Consideration paid consists of the following (in thousands):
				March 31,
	Final			2014			Change			Cash paid, net of cash acquired	$	67,842
	(in thousands)									Value of common units issued	5,248
Accounts receivable - trade	$	6,837		$	7,268		$	(431	)	Total consideration paid	$	73,090
Inventories	154			154			—
Prepaid expenses and other current assets	402			402			—			Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Property, plant and equipment:
Vehicles (5–10 years)	8,143			8,157			(14		)	Retail Propane and Liquids Acquisitions
Water treatment facilities and equipment (3–30 years)	23,173			23,173			—
Buildings and leasehold improvements (7–30 years)	2,198			2,198			—			During the year ended March 31, 2014, we completed four acquisitions of retail propane businesses and the acquisition of four natural gas liquids terminals. On a combined basis, we paid $21.9 million of cash to acquire these assets and operations. The agreements for certain of these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result the estimates of fair value reflected at March 31, 2014 are subject to change.
Land	710			710			—
Other (3–5 years)	53			53			—			Year Ended March 31, 2013
Intangible assets:
Customer relationships (8–10 years)	110,000			110,000			—			High Sierra Combination
Non-compete agreements (3 years)	2,000			2,000			—
Goodwill	90,144			89,699			445			On June 19, 2012, we completed a business combination with High Sierra, whereby we acquired all of the ownership interests in High Sierra. We paid $91.8 million of cash, net of $5.0 million of cash acquired, and issued 18,018,468 common units to acquire High Sierra Energy, LP. These common units were valued at $406.8 million using the closing price of our common units on the New York Stock Exchange (the “NYSE”) on the merger date. We also paid $97.4 million of High Sierra Energy, LP’s long-term debt and other obligations. Our general partner acquired High Sierra Energy GP, LLC by paying $50.0 million of cash and issuing equity. Our general partner then contributed its ownership interests in High Sierra Energy GP, LLC to us, in return for which we paid our general partner $50.0 million of cash and issued 2,685,042 common units to our general partner. We recorded the value of the 2,685,042 common units issued to our general partner at $8.0 million, which represents an estimate, in accordance with GAAP, of the fair value of the equity issued by our general partner to the former owners of High Sierra’s general partner. In accordance with the GAAP fair value model, this fair value was estimated based on assumptions of future distributions and a discount rate that a hypothetical buyer might use. Under this model, the potential for distribution growth resulting from the prospect of future acquisitions and capital expansion projects would not be considered in the fair value calculation. The difference between the estimated fair value of the general partner interests issued by our general partner of $8.0 million, calculated as described above, and the fair value of the common units issued to our general partner of $60.6 million, as calculated using the closing price of the common units on the NYSE, is reported as a reduction to equity. We incurred and charged to general and administrative expense during the years ended March 31, 2013 $3.7 million of costs related to the High Sierra transaction. We also incurred or accrued costs of $0.6 million related to the equity issuance that we charged to equity.
Accounts payable - trade	(6,469		)	(6,469		)	—
Accrued expenses and other payables	(992		)	(992		)	—			The fair values of the assets acquired and liabilities assumed in our acquisition of High Sierra are summarized below (in thousands):
Other noncurrent liabilities	(64		)	(64		)	—
Fair value of net assets acquired	$	236,289		$	236,289		$	—		Accounts receivable - trade	$	395,311
										Accounts receivable - affiliates	7,724
We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.										Inventories	43,575
										Derivative assets	10,646
Other Water Solutions Acquisitions										Forward purchase and sale contracts	34,717
										Prepaid expenses and other current assets	11,131
During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our water solutions operations in Texas. On a combined basis, we issued 222,381 common units, valued at $6.8 million, and paid $151.6 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:										Property, plant and equipment:
										Land	5,723
				Estimated						Vehicles (5—10 years)	22,507
				at						Water treatment facilities and equipment (3—30 years)	64,057
				March 31,						Crude oil tanks and related equipment (2—15 years)	17,851
	Final			2014			Change			Buildings and leasehold improvements (5—30 years)	19,145
	(in thousands)									Information technology equipment (3 years)	5,541
Accounts receivable - trade	$	2,146		$	2,146		$	—		Other (2—30 years)	11,010
Inventories	192			192			—			Construction in progress	9,621
Prepaid expenses and other current assets	62			61			1			Intangible assets:
Property, plant and equipment:										Customer relationships (5—17 years)	245,000
Vehicles (5–10 years)	76			90			(14		)	Lease contracts (1—10 years)	12,400
Water treatment facilities and equipment (3–30 years)	11,717			14,394			(2,677		)	Trade names (indefinite)	13,000
Buildings and leasehold improvements (7–30 years)	3,278			1,906			1,372			Goodwill	220,884
Land	207			206			1			Accounts payable - trade	(417,369			)
Other (3–5 years)	12			12			—			Accounts payable - affiliates	(9,014			)
Intangible assets:										Advance payments received from customers	(1,237			)
Customer relationships (8–10 years)	72,000			72,000			—			Accrued expenses and other payables	(35,611			)
Trade names (indefinite life)	3,325			3,325			—			Derivative liabilities	(5,726			)
Non-compete agreements (3 years)	260			260			—			Forward purchase and sale contracts	(18,680			)
Water facility development agreement (5 years)	14,000			14,000			—			Long-term debt	(2,537			)
Water facility option agreement	2,500			2,500			—			Other noncurrent liabilities	(3,224			)
Goodwill	49,067			47,750			1,317			Noncontrolling interest in consolidated subsidiary	(2,400			)
Accounts payable - trade	(119		)	(119		)	—			Consideration paid, net of cash acquired	$		654,045
Accrued expenses and other payables	(293		)	(293		)	—
Other noncurrent liabilities	(64		)	(64		)	—
Fair value of net assets acquired	$	158,366		$	158,366		$	—		Consideration paid consists of the following (in thousands):
As part of one of these business combinations, we entered into an option agreement with the seller of the business whereby we had the option to purchase a saltwater disposal facility that was under construction. We recorded an intangible asset of $2.5 million at the acquisition date related to this option agreement. On March 1, 2014, we purchased the saltwater disposal facility for additional cash consideration of $3.7 million.										Cash paid, net of cash acquired	$	239,251
										Value of common units issued, net of issurance costs	414,794
In addition, as part of one of these business combinations, we entered into a development agreement that provides us a right to purchase water disposal facilities that may be developed by the seller through June 2018. On March 1, 2014, we purchased our first water disposal facility pursuant to the development agreement for $21.0 million.										Total consideration paid	$	654,045
We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in these business combinations. The estimates of fair value reflected at September 30, 2014 are subject to change, and such changes could be material. We expect to complete this process prior to finalizing our financial statements for the quarter ending December 31, 2014. We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows:										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts.
	Estimated At									Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
	September 30,			March 31,
	2014			2014			Change			Pecos Combination
	(in thousands)
Accounts receivable - trade	$	124		$	245		$	(121	)	On November 1, 2012, we completed a business combination whereby we acquired Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”). The business of Pecos consists primarily of crude oil marketing and logistics operations in Texas and New Mexico. We paid $132.4 million of cash (net of cash acquired) and assumed certain obligations with a value of $10.2 million under certain equipment financing facilities. Also on November 1, 2012, we entered into a call agreement with the former owners of Pecos pursuant to which the former owners of Pecos agreed to purchase a minimum of $45.0 million or a maximum of $60.0 million of common units from us. On November 12, 2012, the former owners purchased 1,834,414 common units from us for $45.0 million pursuant to this call agreement. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.6 million of costs related to the Pecos combination.
Inventories	119			197			(78		)
Property, plant and equipment:										The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of Pecos:
Water treatment facilities and equipment (3–30 years)	10,539			10,540			(1		)
Buildings and leasehold improvements (7–30 years)	1,130			1,130			—							Estimated at
Land	213			213			—							March 31,
Other (3–5 years)	1			1			—				Final			2013			Change
Goodwill	15,443			15,281			162				(in thousands)
Accounts payable - trade	(232		)	(263		)	31			Accounts receivable - trade	$	73,609		$	73,704		$	(95	)
Accrued expenses and other payables	—			(7		)	7			Inventories	1,903			1,903			—
Other noncurrent liabilities	(50		)	(50		)	—			Prepaid expenses and other current assets	1,426			1,426			—
Fair value of net assets acquired	$	27,287		$	27,287		$	—		Property, plant and equipment:
										Vehicles (5—10 years)	22,097			19,193			2,904
Crude Oil Logistics Acquisitions										Buildings and leasehold improvements (5—30 years)	1,339			1,248			91
										Crude oil tanks and related equipment (2—15 years)	1,099			913			186
During the year ended March 31, 2014, we completed two separate acquisitions of businesses to expand our crude oil logistics operations in Texas and Oklahoma. On a combined basis, we issued 175,211 common units, valued at $5.3 million, and paid $67.8 million of cash, net of cash acquired, in exchange for the assets and operations of these businesses. During the three months ended June 30, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair values of the assets acquired (and useful lives) and liabilities assumed for these acquisitions:										Land	223			224			(1		)
										Other (3—5 years)	36			177			(141		)
				Estimated						Intangible assets:
				at						Customer relationships	—			8,000			(8,000		)
				March 31,						Trade names (indefinite life)	900			1,000			(100		)
	Final			2014			Change			Goodwill	91,747			86,661			5,086
	(in thousands)									Accounts payable - trade	(50,795		)	(50,808		)	13
Accounts receivable - trade	$	1,221		$	1,235		$	(14	)	Accrued expenses and other payables	(963		)	(1,020		)	57
Inventories	1,021			1,021			—			Long-term debt	(10,234		)	(10,234		)	—
Prepaid expenses and other current assets	58			54			4			Fair value of net assets acquired	$	132,387		$	132,387		$	—
Property, plant and equipment:
Vehicles (5–10 years)	2,980			2,977			3			Consideration paid consists of the following (in thousands):
Buildings and leasehold improvements (5–30 years)	58			280			(222		)
Crude oil tanks and related equipment (2–30 years)	3,822			3,462			360			Cash paid, net of cash acquired	$	87,444
Barges and towboats (20 years)	20,065			20,065			—			Value of common units issued	44,943
Other (3–5 years)	57			53			4			Total consideration paid	$	132,387
Intangible assets:
Customer relationships (3 years)	13,300			6,300			7,000			Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
Non-compete agreements (3 years)	35			35			—
Trade names (indefinite life)	530			530			—			Third Coast Combination
Goodwill	30,730			37,867			(7,137		)
Accounts payable - trade	(521		)	(665		)	144			On December 31, 2012, we completed a business combination transaction whereby we acquired all of the membership interests in Third Coast Towing, LLC (“Third Coast”) for $43.0 million in cash. The business of Third Coast consists primarily of transporting crude oil via barge. Also on December 31, 2012, we entered into a call agreement with the former owners of Third Coast pursuant to which the former owners of Third Coast agreed to purchase a minimum of $8.0 million or a maximum of $10.0 million of common units from us. On January 11, 2013, the former owners of Third Coast purchased 344,680 common units from us for $8.0 million pursuant to this agreement.
Accrued expenses and other payables	(266		)	(124		)	(142		)
Fair value of net assets acquired	$	73,090		$	73,090		$	—		During the year ended March 31, 2014, we completed the acquisition accounting for this business combination. The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of Third Coast:
Retail Propane and Liquids Acquisitions														Estimated at
														March 31,
During the year ended March 31, 2014, we completed four acquisitions of retail propane businesses and the acquisition of four natural gas liquids terminals. On a combined basis, we paid $21.9 million of cash to acquire these assets and operations. The agreements for certain of these acquisitions contemplate post-closing payments for certain working capital items. We are in the process of identifying and determining the fair value of the assets acquired and liabilities assumed in certain of these business combinations, and as a result, the estimates of fair value reflected at September 30, 2014 are subject to change.											Final			2013			Change
											(in thousands)
										Accounts receivable - trade	$	2,195		$	2,248		$	(53	)
										Inventories	140			140			—
										Property, plant and equipment:
										Barges and towboats (20 years)	17,711			12,883			4,828
										Other	—			30			(30		)
										Intangible assets:
										Customer relationships (3 years)	3,000			4,000			(1,000		)
										Trade names (indefinite life)	850			500			350
										Goodwill	18,847			22,551			(3,704		)
										Other noncurrent assets	2,733			2,733			—
										Accounts payable - trade	(2,429		)	(2,048		)	(381		)
										Accrued expenses and other payables	(164		)	(154		)	(10		)
										Fair value of net assets acquired	$	42,883		$	42,883		$	—
										Consideration paid consists of the following (in thousands):
										Cash paid, net of cash acquired	$	35,000
										Value of common units issued	7,883
										Total consideration paid	$	42,883
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Other Crude Oil Logistics and Water Solutions Business Combinations
										During the year ended March 31, 2013, we completed four separate acquisitions to expand the assets and operations of our crude oil logistics and water solutions businesses. On a combined basis, we paid $52.6 million in cash and assumed $1.3 million of long-term debt in the form of non-compete agreements. We also issued 516,978 common units, valued at $12.4 million, as partial consideration for one of these acquisitions. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.3 million of costs related to these acquisitions.
										During the year ended March 31, 2014, we completed the acquisition accounting for these business combinations. The following table presents the final calculation of the fair value of the assets acquired (and useful lives) and liabilities assumed in the acquisition of these businesses:
														Estimated at
														March 31,
											Final			2013			Change
											(in thousands)
										Accounts receivable - trade	$	2,676		$	2,660		$	16
										Inventories	191			191			—
										Prepaid expenses and other current assets	737			738			(1		)
										Property, plant and equipment:
										Land	218			191			27
										Vehicles (5—10 years)	853			771			82
										Water treatment facilities and equipment (3—30 years)	13,665			13,322			343
										Buildings and leasehold improvements (5—30 years)	895			2,233			(1,338		)
										Crude oil tanks and related equipment (2—15 years)	4,510			1,781			2,729
										Other (3—5 years)	27			2			25
										Construction in progress	490			693			(203		)
										Intangible assets:
										Customer relationships (5—10 years)	13,125			6,800			6,325
										Non-compete agreements (3 years)	164			510			(346		)
										Trade names (indefinite life)	2,100			500			1,600
										Goodwill	34,451			43,822			(9,371		)
										Accounts payable - trade	(3,374		)	(3,374		)	—
										Accrued expenses and other payables	(1,914		)	(2,026		)	112
										Notes payable	(1,340		)	(1,340		)	—
										Other noncurrent liabilities	(156		)	(156		)	—
										Noncontrolling interest	(2,333		)	(2,333		)	—
										Fair value of net assets acquired	$	64,985		$	64,985		$	—
										Consideration paid consists of the following (in thousands):
										Cash paid, net of cash acquired	$	52,552
										Value of common units issued	12,433
										Total consideration paid	$	64,985
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										Retail Propane Combinations During the Year Ended March 31, 2013
										During the year ended March 31, 2013, we entered into six separate business combination agreements to acquire retail propane and distillate operations, primarily in the northeastern and southeastern United States. On a combined basis, we paid cash of $71.4 million and issued 850,676 common units, valued at $18.9 million, in exchange for these assets. We also assumed $6.6 million of long-term debt in the form of non-compete agreements. We incurred and charged to general and administrative expense during the year ended March 31, 2013 $0.3 million related to these acquisitions. The fair values of the assets acquired and liabilities assumed in these six combinations are as follows (in thousands):
										Accounts receivable - trade	$	8,715
										Inventory	5,155
										Other current assets	1,228
										Property, plant and equipment:
										Land	1,945
										Retail propane equipment (5—20 years)	28,763
										Vehicles (5 years)	11,344
										Buildings and leasehold improvements (30 years)	7,052
										Other	1,201
										Intangible assets:
										Customer relationships (10—15 years)	16,890
										Trade names (indefinite)	2,924
										Non-compete agreements (5 years)	1,387
										Goodwill	21,983
										Other non-current assets	784
										Long-term debt, including current portion	(6,594		)
										Other assumed liabilities	(12,511		)
										Fair value of net assets acquired	$	90,266
										Consideration paid consists of the following (in thousands):
										Cash consideration paid	$	71,392
										Value of common units issued	18,874
										Total consideration	$	90,266
										Goodwill represents the excess of the estimated consideration paid for the acquired businesses over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Pro Forma Results of Operations (Unaudited)
										As described above, we completed a number of acquisitions during the years ended March 31, 2014 and 2013. The operations of each acquired business have been included in our consolidated results of operations since the date of acquisition of the business. The unaudited pro forma consolidated data presented below has been prepared as if the following acquisitions had been completed on April 1, 2012:
										·                  High Sierra;
										·                  Pecos;
										·                  Third Coast;
										·                  OWL; and
										·                  Gavilon Energy.
										The unaudited pro forma consolidated data presented below has also been prepared as if the following transactions, which are described in Notes 8 and 11 to these consolidated financial statements, had been completed on April 1, 2012:
										·                  Our sale of common units in December 2013 in a private placement;
										·                  The amendment of our Credit Agreement in November 2013;
										·                  Our issuance of senior unsecured notes in October 2013;
										·                  Our sale of common units in September 2013 in a public offering;
										·                  The sale of common units in a public offering in July 2013;
										·                  Our entry into the Credit Agreement in June 2012; and
										·                  Our issuance of senior notes in June 2012.
											Year Ended March 31,
											2014			2013
											(in thousands, except per unit amounts)
										Revenues	$	9,800,398		$	5,697,988
										Net income (loss)	798			(72,171		)
										Net loss attributable to limited partners	(14,446		)	(75,251		)
										Basic and diluted loss per common unit	(0.18		)	(0.95		)
										Basic and diluted loss per subordinated unit	(0.18		)	(0.95		)
										The pro forma consolidated data in the table above was prepared by adding historical results of operations of acquired businesses to our historical results of operations and making certain pro forma adjustments. The pro forma information is not necessarily indicative of the results of operations that would have occurred if the transactions had occurred on April 1, 2012, nor is it necessarily indicative of future results of operations.
										Gavilon Energy historically conducted trading operations, whereas we operate as a logistics business. Gavilon Energy’s historical results of operations were subject to more volatility as a result of its trading operations than we would expect future results of operations to have under our business model. In the pro forma data in the table above, no pro forma effect was given to the change in business model from a trading business to a logistics business. Gavilon Energy historically recorded revenues net of product costs. In the pro forma table above, no pro forma effect was given to the fact that this accounting policy is different than our accounting policy.
										The pro forma net loss for the year ended March 31, 2013 in the table above includes $4.8 million of expense related to the retirement of a liability associated with a business combination that OWL completed prior to our acquisition of OWL. This non-recurring expense is not excluded from the pro forma net loss, as it does not directly result from our acquisition of OWL.
										The pro forma net loss for the year ended March 31, 2014 shown in the table above reflects depreciation and amortization expense estimates which are preliminary, as our identification of the assets and liabilities acquired, and the fair value determinations thereof, for the business combination with Gavilon Energy have not been completed.
										The pro forma losses per unit have been computed based on earnings or losses allocated to the limited partners after deducting the total earnings allocated to the general partner. To calculate earnings attributable to the general partner, we have used historical distribution amounts. For purposes of this calculation, we have assumed that the common units outstanding at March 31, 2014 were outstanding during the full years presented above.
										Year Ended March 31, 2012
										Osterman
										On October 3, 2011, we completed a business combination transaction with Osterman, whereby we acquired retail propane operations in the northeastern United States. We issued 4,000,000 common units and paid $94.9 million of cash, net of cash acquired, in exchange for the assets and operations of Osterman. The agreement also contemplated a post-closing payment of $4.8 million for certain specified working capital items, which was paid in November 2012. We valued the 4 million limited partner common units at $81.9 million based on the closing price of our common units on the closing date ($20.47 per unit). We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.8 million of costs incurred in connection with the Osterman transaction. We also incurred costs related to the equity issuance of $0.1 million that we charged to equity. The following table presents the final allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	9,350
										Inventories	3,869
										Prepaid expenses and other current assets	215
										Property, plant and equipment:
										Land	2,349
										Retail propane equipment (15—20 years)	47,160
										Vehicles (5—20 years)	7,699
										Buildings and leasehold improvements (30 years)	3,829
										Other (3—5 years)	732
										Intangible assets:
										Customer relationships (20 years)	54,500
										Trade names (indefinite life)	8,500
										Non-compete agreements (7 years)	700
										Goodwill	52,267
										Assumed liabilities	(9,654		)
										Consideration paid, net of cash acquired	$	181,516
										Consideration paid consists of the following (in thousands):
										Cash paid at closing, net of cash acquired	$	94,873
										Fair value of common units issued at closing	81,880
										Working capital payment (paid in November 2012)	4,763
										Consideration paid, net of cash acquired	$	181,516
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										SemStream
										On November 1, 2011, we completed a business combination with SemStream. We entered into this business combination in order to expand our liquids segment. SemStream contributed substantially all of its natural gas liquids business and assets to us in exchange for 8,932,031 of our limited partner common units and a cash payment of $91.0 million. We have valued the 8.9 million limited partner common units at $184.8 million, based on the closing price of our common units on the closing date ($21.07) reduced by the expected present value of distributions for certain units which were not eligible for full distributions until the quarter ending September 30, 2012. In addition, in exchange for a cash contribution, SemStream acquired a 7.5% interest in our general partner. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.7 million of costs related to the SemStream transaction. We also incurred costs of less than $0.1 million related to the equity issuance that we charged to equity.
										The acquired assets included 12 natural gas liquids terminals in Arizona, Arkansas, Indiana, Minnesota, Missouri, Montana, Washington and Wisconsin, 12 million gallons of aboveground propane storage, 3.7 million barrels of underground leased storage for natural gas liquids and a rail fleet of 350 leased and 12 owned cars.
										We have included the results of SemStream’s operations in our consolidated financial statements beginning November 1, 2011. The operations of SemStream are reflected in our liquids segment.
										The following table presents the fair values of the assets acquired and liabilities assumed in the SemStream combination (in thousands):
										Inventories	$	104,226
										Derivative assets	3,578
										Assets held for sale	3,000
										Prepaid expenses and other current assets	9,833
										Property, plant and equipment:
										Land	3,470
										Natural gas liquids terminal assets (20—30 years)	41,434
										Vehicles and railcars (5 years)	470
										Other (5 years)	3,326
										Investment in capital lease	3,112
										Intangible assets:
										Customer relationships (8—15 years)	31,950
										Lease contracts (1—4 years)	1,008
										Goodwill	74,924
										Assumed current liabilities	(4,591		)
										Consideration paid	$	275,740
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired operations and the Partnership, the opportunity to use the acquired businesses as a platform to expand our wholesale marketing operations, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Pacer Combination
										On January 3, 2012, we completed a business combination with Pacer in order to expand our retail propane operations. The combination was funded with cash of $32.2 million and the issuance of 1.5 million common units. We valued the 1.5 million common units based on the closing price of our common units on the closing date. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $0.7 million of costs related to the Pacer transaction. We also incurred costs of $0.1 million related to the equity issuance that we charged to equity.
										The assets contributed by Pacer consist of retail propane operations in Colorado, Illinois, Mississippi, Oregon, Utah and Washington. The contributed assets include 17 owned or leased customer service centers and satellite distribution locations. We have included the results of Pacer’s operations in our consolidated financial statements beginning January 3, 2012. The operations of Pacer are reported within our retail propane segment.
										Consideration paid consists of the following (in thousands):
										Cash	$	32,213
										Common units	30,375
										Consideration paid	$	62,588
										The following table presents the allocation of the acquisition cost to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	4,389
										Inventories	965
										Prepaid expenses and other current assets	43
										Property, plant and equipment:
										Land	1,967
										Retail propane equipment (15—20 years)	12,793
										Vehicles (5 years)	3,090
										Buildings and leasehold improvements (30 years)	409
										Other (3—5 years)	59
										Intangible assets:
										Customer relationships (15 years)	23,560
										Trade names (indefinite life)	2,410
										Non-compete agreements	1,520
										Goodwill	15,782
										Assumed liabilities	(4,399		)
										Consideration paid	$	62,588
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										North American Combination
										On February 3, 2012, we completed a business combination with North American in order to expand our retail propane operations. The combination was funded with cash of $69.8 million. We incurred and charged to general and administrative expense during the year ended March 31, 2012 $1.6 million of costs related to the North American acquisition.
										The assets acquired from North American include retail propane and distillate operations in Connecticut, Delaware, Maine, Maryland, Massachusetts, New Hampshire, New Jersey, Pennsylvania, and Rhode Island.
										The following table presents the allocation of the acquisition costs to the assets acquired and liabilities assumed, based on their fair values (in thousands):
										Accounts receivable - trade	$	10,338
										Inventories	3,437
										Prepaid expenses and other current assets	282
										Property, plant and equipment:
										Land	2,251
										Retail propane equipment (15—20 years)	24,790
										Natural gas liquids terminal assets (15—20 years)	1,044
										Vehicles (5—15 years)	5,819
										Buildings and leasehold improvements (30 years)	2,386
										Other (3—5 years)	634
										Intangible assets:
										Customer relationships (10 years)	12,600
										Trade names (10 years)	2,700
										Non-compete agreements (3 years)	700
										Goodwill	13,978
										Assumed liabilities	(11,129		)
										Consideration paid	$	69,830
										Goodwill represents the excess of the estimated consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities. Goodwill primarily represents the value of synergies between the acquired entities and the Partnership, the opportunity to use the acquired businesses as a platform for growth, and the acquired assembled workforce. We estimate that all of the goodwill will be deductible for federal income tax purposes.
										We estimated the value of the customer relationship intangible asset using the income approach, which uses valuation techniques to convert future amounts (for example, cash flows or earnings) to a single present amount (discounted). The measurement is based on the value indicated by current market expectations about those future amounts. We estimated the useful life of the customer relationships by reference to historical customer retention data.
										Other Acquisitions
										During the year ended March 31, 2012, we closed three additional acquisitions for cash payments of $6.4 million on a combined basis. We also assumed $0.6 million in long-term debt in the form of non-compete agreements. These operations have been included in our results of operations since the acquisition dates, and have not been material to our consolidated financial statements.

Property_Plant_and_Equipment1

Property, Plant and Equipment	6 Months Ended						12 Months Ended
	Sep. 30, 2014						Mar. 31, 2014
Property, Plant and Equipment
Property, Plant and Equipment	Note 5 — Property, Plant and Equipment						Note 5 — Property, Plant and Equipment
	Our property, plant and equipment consists of the following:						Our property, plant and equipment consists of the following:
		September 30,		March 31,				March 31,
	Description and Estimated Useful Lives	2014		2014							2013
		(in thousands)					Description and Estimated Useful Lives	2014			(Note 2)
	Natural gas liquids terminal assets (2–30 years)	$	127,258	$	75,141			(in thousands)
	Refined products and renewables terminal assets and equipment (20 years)	419,411		—			Natural gas liquids terminal assets (2—30 years)	$	75,141		$	63,637
	Retail propane equipment (2–30 years)	167,825		160,758			Retail propane equipment (2—30 years)	160,758			152,802
	Vehicles and railcars (3–25 years)	172,799		152,676			Vehicles (3—25 years)	152,676			88,173
	Water treatment facilities and equipment (3–30 years)	209,644		180,985			Water treatment facilities and equipment (3—30 years)	180,985			91,944
	Crude oil tanks and related equipment (2–40 years)	145,287		106,125			Crude oil tanks and related equipment (2—40 years)	106,125			22,577
	Barges and towboats (5–40 years)	56,094		52,217			Barges and towboats (5—40 years)	52,217			25,963
	Information technology equipment (3–7 years)	30,519		20,768			Information technology equipment (3—7 years)	20,768			12,169
	Buildings and leasehold improvements (3–40 years)	77,415		60,004			Buildings and leasehold improvements (3—40 years)	60,004			48,975
	Land	88,350		30,241			Land	30,241			21,815
	Tank bottoms	17,679		13,403			Linefill and tank bottoms	13,403			—
	Other (3–30 years)	16,770		6,341			Other (5—30 years)	6,341			16,104
	Construction in progress	57,319		80,251			Construction in progress	80,251			32,405
		1,586,370		938,910				938,910			576,564
	Less: Accumulated depreciation	-153,057		(109,564		)	Less: Accumulated depreciation	(109,564		)	(50,127		)
	Net property, plant and equipment	$	1,433,313	$	829,346		Net property, plant and equipment	$	829,346		$	526,437
	Depreciation expense was $28.4 million and $13.7 million during the three months ended September 30, 2014 and 2013, respectively, and $46.9 million and $27.2 million during the six months ended September 30, 2014 and 2013, respectively.						Depreciation expense was $59.9 million, $39.2 million and $10.6 million during the years ended March 31, 2014, 2013 and 2012, respectively. During the year ended March 31, 2014, we capitalized $0.7 million of interest expense.
	Crude oil volumes required for the operation of storage tanks, known as tank bottoms, are recorded at historical cost. Tank bottoms are the volume of crude oil that must be maintained in a storage tank to enable operation of the storage tank. We recover tank bottom crude oil when we no longer use the storage tanks or the storage tanks are removed from service. At September 30, 2014, tank bottoms consisted of approximately 185,000 barrels.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	6 Months Ended
	Sep. 30, 2014
Goodwill and Intangible Assets
Goodwill and Intangible Assets	Note 6 — Goodwill and Intangible Assets
	The changes in the balance of goodwill during the six months ended September 30, 2014 were as follows (in thousands):
	Beginning of period	$	1,107,006
	Revisions to acquisition accounting (Note 4)	(21,614		)
	Acquisitions (Note 4)	86,895
	Disposal	(1,797		)
	End of period	$	1,170,490
	Goodwill by reportable segment is as follows:
		September 30,			March 31,
		2014			2014
		(in thousands)
	Crude oil logistics	$	579,845		$	606,383
	Water solutions	320,106			262,203
	Liquids	91,135			90,135
	Retail propane	114,285			114,285
	Refined products and renewables	65,119			34,000
	Total	$	1,170,490		$	1,107,006
	Our intangible assets consist of the following:
				September 30, 2014						March 31, 2014
		Amortizable		Gross Carrying			Accumulated			Gross Carrying			Accumulated
		Lives		Amount			Amortization			Amount			Amortization
				(in thousands)
	Amortizable —
	Customer relationships (1)	3–20 years		$	761,992		$	119,439		$	697,405		$	83,261
	Pipeline capacity rights	30 years		94,800			942			—			—
	Water facility development agreement	5 years		14,000			3,500			14,000			2,100
	Executory contracts and other agreements	5–10 years		23,920			16,367			23,920			13,190
	Non-compete agreements	2–7 years		14,412			8,302			14,161			6,388
	Trade names	2–10 years		14,539			5,197			15,489			3,081
	Debt issuance costs	5–10 years		53,289			12,737			44,089			8,708
	Total amortizable			976,952			166,484			809,064			116,728
	Non-amortizable —
	Trade names			27,620						22,620
	Total			$	1,004,572		$	166,484		$	831,684		$	116,728
	(1)     The weighted-average remaining amortization period for customer relationship intangible assets is approximately 9 years.
	Amortization expense is as follows:
		Three Months Ended						Six Months Ended
		September 30,						September 30,
	Recorded In	2014			2013			2014			2013
		(in thousands)
	Depreciation and amortization	$	21,711		$	11,324		$	42,604		$	20,600
	Cost of sales	1,984			949			4,121			1,574
	Interest expense	2,117			1,065			4,029			2,462
	Total	$	25,812		$	13,338		$	50,754		$	24,636
	Expected amortization of our intangible assets is as follows (in thousands):
	Year Ending March 31,
	2015 (six months)	$	50,570
	2016	97,432
	2017	90,795
	2018	86,818
	2019	79,587
	Thereafter	405,266
	Total	$	810,468

LongTerm_Debt

Long-Term Debt	6 Months Ended																12 Months Ended
	Sep. 30, 2014																Mar. 31, 2014
Long-Term Debt
Long-Term Debt	Note 7 — Long-Term Debt																Note 8 — Long-Term Obligations
	Our long-term debt consists of the following:																Our long-term debt consists of the following:
		September 30,			March 31,													March 31,
		2014			2014													2014		2013
		(in thousands)																(in thousands)
	Revolving credit facility —																Revolving credit facility —
	Expansion capital borrowings	$	137,000		$	532,500											Expansion capital loans	$	532,500	$	441,500
	Working capital borrowings	942,500			389,500												Working capital loans	389,500		36,000
	5.125% Notes due 2019	400,000			—												Senior notes	250,000		250,000
	6.875% Notes due 2021	450,000			450,000												Unsecured notes	450,000		—
	6.650% Notes due 2022	250,000			250,000												Other notes payable	14,914		21,562
	TLP credit facility	252,000			—													1,636,914		749,062
	Other long-term debt	10,913			14,914
		2,442,413			1,636,914												Less - current maturities	7,080		8,626
	Less - current maturities	5,062			7,080												Long-term debt	$	1,629,834	$	740,436
	Long-term debt	$	2,437,351		$	1,629,834
																	Credit Agreement
	Credit Agreement
																	On June 19, 2012, we 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”).
	On June 19, 2012, we 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”).
																	The Working Capital Facility had a total capacity of $935.5 million for cash borrowings and letters of credit at March 31, 2014. At March 31, 2014, we had outstanding cash borrowings of $389.5 million and outstanding letters of credit of $270.6 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $785.5 million for cash borrowings at March 31, 2014. At March 31, 2014, we had outstanding cash borrowings of $532.5 million on the Expansion 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 Working Capital Facility had a total capacity of $1.335 billion for cash borrowings and letters of credit at September 30, 2014. At that date, we had outstanding borrowings of $942.5 million and outstanding letters of credit of $209.2 million on the Working Capital Facility. The Expansion Capital Facility had a total capacity of $858.0 million for cash borrowings at September 30, 2014. At that date, we had outstanding borrowings of $137.0 million on the Expansion 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 pre-pay outstanding borrowings under the Credit Agreement without incurring any penalties, and pre-payments of principal may be required if we enter into certain transactions to sell assets or obtain new borrowings.
	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 (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At March 31, 2014, the interest rate in effect on outstanding LIBOR borrowings was 1.91%, calculated as the LIBOR rate of 0.16% plus a margin of 1.75%. At March 31, 2014, the interest rate in effect on letters of credit was 1.75%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At March 31, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
	All borrowings under the Credit Agreement bear interest, at our option, at (i) an alternate base rate plus a margin of 0.50% to 1.50% per annum or (ii) an adjusted LIBOR rate plus a margin of 1.50% to 2.50% per annum. The applicable margin is determined based on our consolidated leverage ratio, as defined in the Credit Agreement. At September 30, 2014, all borrowings under the Credit Agreement were LIBOR borrowings with an interest rate at September 30, 2014 of 1.91%, calculated as the LIBOR rate of 0.16% plus a margin of 1.75%. At September 30, 2014, the interest rate in effect on letters of credit was 2.00%. Commitment fees are charged at a rate ranging from 0.38% to 0.50% on any unused credit. At September 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
																		Amount		Rate
		Amount			Rate												Expansion capital facility —
	Expansion Capital Facility —																LIBOR borrowings	$	532,500	1.91	%
	LIBOR borrowings	$	137,000		1.91	%											Working capital facility —
	Working Capital Facility —																LIBOR borrowings	358,000		1.91	%
	LIBOR borrowings	942,500			1.91	%											Base rate borrowings	31,500		4	%
	The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our leverage ratio, as defined in the Credit Agreement, cannot exceed 4.25 to 1 at any quarter end. At September 30, 2014, our leverage ratio was approximately 3.4 to 1. The Credit Agreement also specifies that our interest coverage ratio, as defined in the Credit Agreement, cannot be less than 2.75 to 1 at any quarter end. At September 30, 2014, our interest coverage ratio was approximately 4.8 to 1.																The Credit Agreement is secured by substantially all of our assets. The Credit Agreement specifies that our “leverage ratio,” as defined in the Credit Agreement, cannot exceed 4.25 to 1.0 at any quarter end. At March 31, 2014, our leverage ratio was approximately 3 to 1. The Credit Agreement also specifies that our “interest coverage ratio,” as defined in the Credit Agreement, cannot be less than 2.75 to 1 as of the last day of any fiscal quarter. At March 31, 2014, our interest coverage ratio was approximately 7 to 1.
	The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.																The Credit Agreement contains various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the Credit Agreement may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) a breach by the Partnership or its subsidiaries of any material representation or warranty or any covenant made in the Credit Agreement, or (iii) certain events of bankruptcy or insolvency.
	At September 30, 2014, we were in compliance with the covenants under the Credit Agreement.																At March 31, 2014, we were in compliance with the covenants under the Credit Agreement.
	2019 Notes																Senior Notes
	On July 9, 2014, we issued $400.0 million of 5.125% Senior Notes Due 2019 (the “2019 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 $393.5 million, after the initial purchasers’ discount of $6.0 million and estimated offering costs of $0.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.																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 “Senior Notes”). The Senior Notes have an aggregate principal amount of $250.0 million and bear interest at a fixed rate of 6.65%. Interest is payable quarterly. The Senior 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 pre-pay outstanding principal, although we would incur a pre-payment penalty. The Senior Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.
	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 prior to the maturity date, although we would be required to pay a premium for early redemption.																The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which are described above.
	The Partnership and NGL Energy Finance Corp. are co-issuers of the 2019 Notes, and the obligations under the 2019 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2019 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.																The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) non-payment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the Senior Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the Senior Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding Senior Notes of any series may declare all of the Senior Notes of such series to be due and payable immediately.
	At September 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2019 Notes.																At March 31, 2014, we were in compliance with the covenants under the Note Purchase Agreement and the Senior Notes.
	We also entered into a registration rights agreement whereby we have committed to exchange the 2019 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2019 Notes on or before July 9, 2015. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the 2019 Notes.																Unsecured Notes
	2021 Notes																On October 16, 2013, we issued $450.0 million of 6.875% senior unsecured notes (the “Unsecured 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 $438.4 million, after the initial purchasers’ discount of $10.1 million and estimated offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.
	On October 16, 2013, we issued $450.0 million of 6.875% Senior Notes Due 2021 (the “2021 Notes”) in a private placement exempt from registration under the Securities Act pursuant to Rule 144A and Regulation S under the Securities Act. We received net proceeds of $438.4 million, after the initial purchasers’ discount of $10.1 million and offering costs of $1.5 million. We used the net proceeds to reduce the outstanding balance on our Revolving Credit Facility.																The Unsecured 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 Unsecured Notes prior to the maturity date, although we would be required to pay a premium for early redemption.
	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 prior to the maturity date, although we would be required to pay a premium for early redemption.																The purchase agreement and the indenture governing the Unsecured Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.
	The Partnership and NGL Energy Finance Corp. are co-issuers of the 2021 Notes, and the obligations under the 2021 Notes are guaranteed by certain of our existing and future restricted subsidiaries that incur or guarantee indebtedness under certain of our other indebtedness, including the Revolving Credit Facility. The purchase agreement and the indenture governing the 2021 Notes contain various customary representations, warranties, and additional covenants, including, without limitation, limitations on fundamental changes and limitations on indebtedness and liens. Our obligations under the purchase agreement and the indenture may be accelerated following certain events of default (subject to applicable cure periods), including, without limitation, (i) the failure to pay principal or interest when due, (ii) experiencing an event of default on certain other debt agreements, or (iii) certain events of bankruptcy or insolvency.																At March 31, 2014, we were in compliance with the covenants under the Unsecured Notes.
	At September 30, 2014, we were in compliance with the covenants under the purchase agreement and indenture governing the 2021 Notes.																We also entered into a registration rights agreement whereby we have committed to exchange the Unsecured Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the Unsecured Notes on or before October 16, 2014. If we are unable to fulfill this obligation, we would be required to pay liquidated damages to the holders of the Unsecured Notes.
	We also entered into a registration rights agreement whereby we have committed to exchange the 2021 Notes for a new issue of notes registered under the Securities Act that has substantially identical terms to the 2021 Notes on or before October 16, 2014. Our inability to register the notes on time may result in liquidated damages of approximately $0.1 million per month.																Other Notes Payable
	2022 Notes																We have executed various non-interest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. We also have certain notes payable related to equipment financing, which have interest rates ranging from 2.1% to 4.9% at March 31, 2014.
	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%. Interest 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. The 2022 Notes are secured by substantially all of our assets and rank equal in priority with borrowings under the Credit Agreement.																Debt Maturity Schedule
	The Note Purchase Agreement contains various customary representations, warranties, and additional covenants that, among other things, limit our ability to (subject to certain exceptions): (i) incur additional debt, (ii) pay dividends and make other restricted payments, (iii) create or permit certain liens, (iv) create or permit restrictions on the ability of certain of our subsidiaries to pay dividends or make other distributions to us, (v) enter into transactions with affiliates, (vi) enter into sale and leaseback transactions and (vii) consolidate or merge or sell all or substantially all or any portion of our assets. In addition, the Note Purchase Agreement contains substantially the same leverage ratio and interest coverage ratio requirements as our Credit Agreement, which is described above.																The scheduled maturities of our long-term debt are as follows at March 31, 2014:
	The Note Purchase Agreement provides for customary events of default that include, among other things (subject in certain cases to customary grace and cure periods): (i) nonpayment of principal or interest, (ii) breach of certain covenants contained in the Note Purchase Agreement or the 2022 Notes, (iii) failure to pay certain other indebtedness or the acceleration of certain other indebtedness prior to maturity if the total amount of such indebtedness unpaid or accelerated exceeds $10.0 million, (iv) the rendering of a judgment for the payment of money in excess of $10.0 million, (v) the failure of the Note Purchase Agreement, the 2022 Notes, or the guarantees by the subsidiary guarantors to be in full force and effect in all material respects and (vi) certain events of bankruptcy or insolvency. Generally, if an event of default occurs (subject to certain exceptions), the trustee or the holders of at least 51% in aggregate principal amount of the then outstanding 2022 Notes of any series may declare all of the 2022 Notes of such series to be due and payable immediately.																	Revolving						Other
																		Credit		Senior		Unsecured		Notes
	At September 30, 2014, we were in compliance with the covenants under the Note Purchase Agreement.																Year Ending March 31,	Facility		Notes		Notes		Payable		Total
																						(in thousands)
	TLP Credit Facility																2015	$	—	$	—	$	—	$	7,081	$	7,081
																	2016	—		—		—		3,614		3,614
	On March 9, 2011, TLP entered into an amended and restated senior secured credit facility (“TLP Credit Facility”), which has been subsequently amended from time to time. The TLP Credit Facility provides for a maximum borrowing line of credit equal to the lesser of (i) $350 million and (ii) 4.75 times Consolidated EBITDA (as defined in the TLP Credit Facility: $352.9 million at September 30, 2014). TLP may elect to have loans under the TLP Credit Facility that bear interest either (i) at a rate of LIBOR plus a margin ranging from 2% to 3% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 1% to 2% depending on the total leverage ratio then in effect. TLP also pays a commitment fee on the unused amount of commitments, ranging from 0.375% to 0.50% per annum, depending on the total leverage ratio then in effect. TLP’s obligations under the TLP Credit Facility are secured by a first priority security interest in favor of the lenders in the majority of TLP assets.																2017	—		—		—		2,356		2,356
																	2018	—		25,000		—		1,449		26,449
	The terms of the TLP Credit Facility include covenants that restrict TLP’s ability to make cash distributions, acquisitions and investments, including investments in joint ventures. TLP may make distributions of cash to the extent of its “available cash” as defined in the TLP partnership agreement. TLP may make acquisitions and investments that meet the definition of “permitted acquisitions”; “other investments” which may not exceed 5% of “consolidated net tangible assets”; and “permitted JV investments”. Permitted JV investments include up to $225 million of investments in BOSTCO, the “Specified BOSTCO Investment”. In addition to the Specified BOSTCO Investment, under the terms of the TLP Credit Facility, TLP may make an additional $75 million of other permitted JV investments (including additional investments in BOSTCO). The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date, March 9, 2016.																2019	922,000		50,000		—		238		972,238
																	Thereafter	—		175,000		450,000		176		625,176
	The TLP Credit Facility also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). The primary financial covenants contained in the TLP Credit Facility are (i) a total leverage ratio test (not to exceed 4.75 times), (ii) a senior secured leverage ratio test (not to exceed 3.75 times) in the event TLP issues senior unsecured notes, and (iii) a minimum interest coverage ratio test (not less than 3.0 times).																	$	922,000	$	250,000	$	450,000	$	14,914	$	1,636,914
	If TLP were to fail any financial performance covenant, or any other covenant contained in the TLP Credit Facility, TLP would seek a waiver from its lenders under such facility. If TLP was unable to obtain a waiver from its lenders and the default remained uncured after any applicable grace period, TLP would be in breach of the TLP Credit Facility, and the lenders would be entitled to declare all outstanding borrowings immediately due and payable. TLP was in compliance with all of the financial covenants under the TLP Credit Facility as of September 30, 2014.																Previous Credit Facilities
	At September 30, 2014, TLP had $252.0 million of outstanding borrowings under the TLP Credit Facility and no outstanding letters of credit.																On June 19, 2012, we made a principal payment of $306.8 million to retire our previous revolving credit facility. Upon retirement of this facility, we wrote off the portion of the debt issuance cost asset that had not yet been amortized. This expense is reported as “Loss on early extinguishment of debt” in our consolidated statement of operations for the year ended March 31, 2013.
	The following table summarizes our basis in the assets and liabilities of TLP at September 30, 2014, inclusive of the impact of our acquisition accounting for the business combination with TransMontaigne (in thousands):
Cash and cash equivalents	$	726
Accounts receivable - trade, net	12,252
Accounts receivable - affiliates	1,105
Inventories	1,613
Prepaid expenses and other current assets	1,363
Property, plant and equipment, net	504,272
Goodwill	29,118
Intangible assets, net	38,571
Investments in unconsolidated entities	268,410
Other noncurrent assets	1,910
Accounts payable - trade	(4,009		)
Accounts payable - affiliates	(146		)
Accrued expenses and other payables	(11,625		)
Advanced payments received from customers	(141		)
Long-term debt	(252,000		)
Other noncurrent liabilities	(4,247		)
Net assets	$	587,172
Other Long-Term Debt
We have executed various noninterest bearing notes payable, primarily related to non-compete agreements entered into in connection with acquisitions of businesses. We also have certain notes payable related to equipment financing.
Debt Maturity Schedule
The scheduled maturities of our long-term debt are as follows at September 30, 2014:
	Revolving									TLP		Other
	Credit			2019		2021		2022		Credit		Long-Term
Year Ending March 31,	Facility			Notes		Notes		Notes		Facility		Debt		Total
	(in thousands)
2015 (six months)	$	—		$	—	$	—	$	—	$	—	$	2,345	$	2,345
2016	—			—		—		—		252,000		3,128		255,128
2017	—			—		—		—		—		2,362		2,362
2018	—			—		—		25,000		—		1,459		26,459
2019	1,079,500			—		—		50,000		—		1,438		1,130,938
Thereafter	—			400,000		450,000		175,000		—		181		1,025,181
Total	$	1,079,500		$	400,000	$	450,000	$	250,000	$	252,000	$	10,913	$	2,442,413

Income_Taxes1

Income Taxes	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Income Taxes
Income Taxes	Note 8 — Income Taxes	Note 9 — 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 believe that 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. We utilize the asset and liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply in the years in which these temporary differences are expected to be recovered or settled. Changes in tax rates are recognized in income in the period that includes the enactment date.	We have certain taxable corporate subsidiaries in the United States and Canada. In addition, our operations in Texas are subject to a state franchise tax that is calculated based on revenues net of cost of sales.
	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.	A publicly traded partnership is required to generate at least 90% of its gross income (as defined for federal income tax purposes) from certain qualifying sources. Income generated by our taxable corporate subsidiaries is excluded from this qualifying income calculation. Although we routinely generate income outside of our corporate subsidiaries that is non-qualifying, we believe that at least 90% of our gross income has been qualifying income for each of the calendar years since our IPO.
	We 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 the consolidated financial statements at September 30, 2014.	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 the consolidated financial statements at March 31, 2014.

Commitments_and_Contingencies1

Commitments and Contingencies	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Commitments and Contingencies
Commitments and Contingencies	Note 9 — Commitments and Contingencies					Note 10 — Commitments and Contingencies
	Legal 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, will not 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.					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, will not 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.
	Customer Dispute					Customer Dispute
	A customer of our crude oil logistics segment disputed the transportation rate schedule we used to bill the customer for services that we provided from November 2012 through February 2013, which was the same rate schedule that Pecos Gathering & Marketing, L.L.C. and certain of its affiliated companies (collectively, “Pecos”), used to bill the customer from April 2011 through October 2012 (prior to our November 1, 2012 acquisition of Pecos). The customer disputed a portion of the amount we charged for services we provided from November 2012 through February 2013. In May 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. Later in May 2013, the customer filed an answer and counterclaim seeking to recover certain amounts that it paid to Pecos prior to our acquisition of Pecos.					A customer of our crude oil logistics segment has disputed the transportation rate schedule we used to bill the customer for services that we provided from November 2012 through February 2013, which was the same rate schedule that Pecos used to bill the customer from April 2011 through October 2012 (prior to our acquisition of Pecos). The customer has not paid $1.7 million of the amount we charged for services we provided from November 2012 through February 2013. In May 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. Later in May 2013, the customer filed an answer and counterclaim seeking to recover $5.5 million that it paid to Pecos prior to our acquisition of Pecos. We have not recorded revenue for the $1.7 million of unpaid fees charged from November 2012 through February 2013, pending resolution of the dispute.
	During August 2013, the customer notified us that it intended to withhold payment due for services performed by us during the period from June 2013 through August 2013, pending resolution of the dispute, although the customer did not dispute the validity of the amounts billed for services performed during this time frame. Upon receiving this notification, we ceased providing services under this contract, and on November 5, 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer.					During August 2013, the customer notified us that it intended to withhold payment of $3.3 million for services performed by us during the period from June 2013 through August 2013, pending resolution of the dispute, although the customer has not disputed the validity of the amounts billed for services performed during this time frame. Upon receiving this notification, we ceased providing services under this contract, and on November 5, 2013, we filed a petition in the District Court of Harris County, Texas seeking to collect these unpaid fees from the customer. We are not able to reliably predict the outcome of this dispute at this time, but we do not believe the outcome will have a material adverse effect on our consolidated financial position or results of operations.
	During September 2014, we reached an agreement with the former customer whereby the former customer agreed to pay us an agreed-upon amount to dismiss its claims against us, in return for which we agreed to dismiss our other claims against the former customer. We did not record a gain or loss upon settlement, as the amount we received approximated the amount we had recorded as receivable from the customer.					Canadian Fuel and Sales Taxes
	Environmental Matters					The taxing authority of a province in Canada completed an audit of fuel and sales tax payments and alleged that an entity we acquired should have collected from customers and remitted to the taxing authority fuel and sales taxes on certain historical sales. We recorded in the acquisition accounting a liability of $0.8 million (net of receivables for expected recoveries from other parties). We now believe this matter is resolved, and we removed the liability from our consolidated balance sheet and recorded a corresponding reduction to cost of sales during the year ended March 31, 2014.
	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 significant costs will not be incurred. 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.					Environmental Matters
	Asset Retirement Obligations					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 significant costs will not be incurred. 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.
	We have recorded a liability of $2.7 million at September 30, 2014 for asset retirement obligations. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.					Asset Retirement Obligations
	In addition to the obligations described 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.					We have recorded a liability of $2.3 million at March 31, 2014 for asset retirement obligations. This liability is related to wastewater disposal facilities and crude oil facilities for which we have contractual and regulatory obligations to perform remediation and, in some instances, dismantlement and removal activities when the assets are retired.
	Operating Leases					In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. However, 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.
	We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, railcars, and equipment. Future minimum lease payments under these agreements at September 30, 2014 are as follows (in thousands):					Operating Leases
	Year Ending March 31,					We have executed various noncancelable operating lease agreements for product storage, office space, vehicles, real estate, and equipment. Future minimum lease payments under contractual commitments at March 31, 2014 are as follows (in thousands):
	2015 (six months)	$	71,007
	2016	106,384				Year Ending March 31,
	2017	88,666				2015	$	133,170
	2018	74,265				2016	93,454
	2019	49,907				2017	64,209
	Thereafter	117,125				2018	49,802
	Total	$	507,354			2019	29,213
						Thereafter	58,182
	Rental expense relating to operating leases was $29.3 million and $23.6 million during the three months ended September 30, 2014 and 2013, respectively, and $54.6 million and $45.5 million during the six months ended September 30, 2014 and 2013, respectively.					Total	$	428,030
	Pipeline Capacity Agreements					Rental expense relating to operating leases was $98.3 million, $84.2 million, and $5.2 million during the years ended March 31, 2014, 2013, and 2012, respectively.
	We have executed noncancelable agreements with crude and refined products pipeline operators, which guarantee us minimum monthly shipping capacity on the pipelines. In exchange, we are obligated to pay the minimum shipping fees in the event actual shipments are less than our allotted capacity. Future minimum throughput payments under these agreements at September 30, 2014 are as follows (in thousands):					Sales and Purchase Contracts
	Year Ending March 31,					We have entered into sales and purchase contracts for products to be delivered in future periods for which we expect the parties to physically settle the contracts with inventory. At March 31, 2014, we had the following such commitments outstanding:
	2015 (six months)	$	41,822
	2016	95,050					Volume		Value
	2017	82,916					(in thousands)
	2018	62,565				Natural gas liquids fixed-price purchase commitments (gallons)	31,111		$	39,117
	2019	51,278				Natural gas liquids floating-price purchase commitments (gallons)	522,947		618,293
	Thereafter	107,537				Natural gas liquids fixed-price sale commitments (gallons)	63,944		77,682
	Total	$	441,168			Natural gas liquids floating-price sale commitments (gallons)	272,495		395,095
						Crude oil fixed-price purchase commitments (barrels)	4,016		364,557
	Sales and Purchase Contracts					Crude oil fixed-price sale commitments (barrels)	3,574		324,765
	We have entered into sales and purchase contracts for products to be delivered in future periods for which we expect the parties to physically settle the contracts with inventory. At September 30, 2014, we had the following such commitments outstanding:
						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 (described in Note 12) or inventory positions (described in Note 2).
		Volume		Value
		(in thousands)				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 on our consolidated balance sheet and are not included in the data in the table above. These contracts are included in the derivative disclosures in Note 12, and represent $43.5 million of our prepaid expenses and other current assets and $34.6 million of our accrued expenses and other payables at March 31, 2014.
	Natural gas liquids fixed-price purchase commitments (gallons)	88,574		$	102,000
	Natural gas liquids index-price purchase commitments (gallons)	528,459		601,719
	Natural gas liquids fixed-price sale commitments (gallons)	278,391		351,137
	Natural gas liquids index-price sale commitments (gallons)	370,639		512,900
	Crude oil index-price purchase commitments (barrels)	4,437		383,153
	Crude oil fixed-price sale commitments (barrels)	32		2,867
	Crude oil index-price sale commitments (barrels)	3,920		337,528
	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 (described in Note 11) or inventory positions (described in Note 2).
	Certain other forward purchase and sale contracts do not qualify for the normal purchase and normal sale election. These contracts are recorded at fair value on our condensed consolidated balance sheet and are not included in the table above. These contracts are included in the derivative disclosures in Note 11, and represent $44.4 million of our prepaid expenses and other current assets and $36.3 million of our accrued expenses and other payables at September 30, 2014.

Equity1

Equity	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Equity
Equity	Note 10 — Equity												Note 11 — Equity
	Partnership 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. Prior to August 2014, the Partnership’s limited partner interest also included subordinated units. The subordination period ended in August 2014, at which time all remaining subordinated units were converted into common units on a one-for-one basis.												The Partnership’s equity consists of a 0.1% general partner interest and a 99.9% limited partner interest. Limited partner equity includes common and subordinated units. The common and subordinated units share equally in the allocation of income or loss. The principal difference between common and subordinated units is that in any quarter during the subordination period, holders of the subordinated units are not entitled to receive any distribution until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units will not accrue arrearages.
	Our general partner is not obligated to make any additional capital contributions or to guarantee or pay any of our debts and obligations.												We expect the subordination period to end in August 2014. When the subordination period ends, all remaining subordinated units will convert into common units on a one-for-one basis and the common units will no longer be entitled to arrearages.
	Equity Issuances												Our general partner is not obligated to make any additional capital contributions or to guarantee or pay any of our debts and obligations.
	On June 23, 2014, we completed a public offering of 8,000,000 common units. We received net proceeds of $338.0 million, after underwriting discounts and commissions of $12.3 million and offering costs of $0.5 million. During July 2014, the underwriters exercised their option to purchase an additional 767,100 units, from which we received net proceeds of $32.4 million.												Initial Public Offering
	Distributions to Owners												On May 17, 2011, we completed our IPO. We sold a total of 4,025,000 common units in our IPO at $21.00 per unit. Our proceeds from the sale of 3,850,000 common units of $71.9 million, net of total offering costs of $9.0 million, were used to repay advances under our acquisition credit facility and for general partnership purposes. Proceeds from the sale of 175,000 common units ($3.4 million) from the underwriters’ exercise of their option to purchase additional common units from us were used to redeem 175,000 of the common units outstanding prior to our IPO. Upon the completion of our IPO and the underwriters’ exercise in full of their option to purchase additional common units from us and the redemption, we had outstanding 8,864,222 common units, 5,919,346 subordinated units, a 0.1% general partner interest, and IDRs.
	Our general partner has adopted a cash distribution policy that requires us to pay a quarterly distribution to unitholders as of the record date to the extent we have sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner and its affiliates, referred to as “available cash.” The general partner will also receive, in addition to distributions on its 0.1% general partner interest, additional distributions based on the level of distributions to the limited partners. These distributions are referred to as “incentive distributions.” Our general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in our partnership agreement.												Common Units Issued in Business Combinations
	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest In Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit,” until available cash from operating surplus we distribute reaches the next target distribution level, if any. The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 0.1% general partner interest, assume our general partner has contributed any additional capital necessary to maintain its 0.1% general partner interest and has not transferred its incentive distribution rights.												As described in Note 4, we issued common units as partial consideration for several acquisitions. These are summarized below:
									Marginal Percentage Interest In				Osterman combination	4,000,000
		Total Quarterly							Distributions				SemStream combination	8,932,031
		Distribution Per Unit							Unitholders		General Partner		Pacer combination	1,500,000
	Minimum quarterly distribution						$	0.3375	99.9	%	0.1	%	Total - Year Ended March 31, 2012	14,432,031
	First target distribution	above		$	0.3375	up to	$	0.388125	99.9	%	0.1	%
	Second target distribution	above		$	0.388125	up to	$	0.421875	86.9	%	13.1	%	High Sierra combination	20,703,510
	Third target distribution	above		$	0.421875	up to	$	0.50625	76.9	%	23.1	%	Retail propane combinations	850,676
	Thereafter	above		$	0.50625				51.9	%	48.1	%	Crude oil logistics and water solutions combinations	516,978
													Pecos combination	1,834,414
	During the three months ended September 30, 2014, we distributed a total of $61.5 million ($0.5888 per common, subordinated, and general partner notional unit) to our unitholders of record on August 4, 2014, which included an incentive distribution of $9.5 million to the general partner. In October 2014, we declared a distribution of $0.6088 per common unit, to be paid on November 14, 2014 to unitholders of record on November 4, 2014. This distribution is expected to be $65.0 million, including amounts to be paid on common and general partner notional units and the amount to be paid on incentive distribution rights.												Third Coast combination	344,680
													Total - Year Ended March 31, 2013	24,250,258
	Distributions to Noncontrolling Interest Partners
													Water solutions combinations	222,381
	TLP’s general partner has adopted a cash distribution policy that requires it to pay a quarterly distribution to unitholders as of the record date to the extent TLP has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to TLP’s general partner and its affiliates, referred to as “available cash.” TLP’s general partner will also receive, in addition to distributions on its 2.0% general partner interest, additional distributions based on the level of distributions to the limited partners. These distributions are referred to as “incentive distributions.” TLP’s general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in TLP’s partnership agreement.												Crude oil logistics combinations	175,211
													OWL combination	2,463,287
	The following table illustrates the percentage allocations of available cash from operating surplus between TLP’s unitholders and TLP’s general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest In Distributions” are the percentage interests of TLP’s general partner and TLP’s unitholders in any available cash from operating surplus TLP distributes up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit,” until available cash from operating surplus TLP distributes reaches the next target distribution level, if any. The percentage interests shown for TLP’s unitholders and TLP’s general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for TLP’s general partner include its 2.0% general partner interest, assume TLP’s general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and has not transferred its incentive distribution rights.												Total - Year Ended March 31, 2014	2,860,879
									Marginal Percentage Interest In				In connection with the completion of certain of these transactions, we amended our Registration Rights Agreement, which provides for certain registration rights for certain holders of our common units.
		Total Quarterly							Distributions
		Distribution Per Unit							Unitholders		General Partner		Equity Issuances
	Minimum quarterly distribution						$	0.4	98	%	2	%
	First target distribution	above		$	0.4	up to	$	0.44	98	%	2	%	On July 5, 2013, we completed a public offering of 10,350,000 common units. We received net proceeds of $287.5 million, after underwriting discounts and commissions of $12.0 million and offering costs of $0.7 million.
	Second target distribution	above		$	0.44	up to	$	0.5	85	%	15	%
	Third target distribution	above		$	0.5	up to	$	0.6	75	%	25	%	On September 25, 2013, we completed a public offering of 4,100,000 common units. We received net proceeds of $127.6 million, after underwriting discounts and commissions of $5.0 million and offering costs of $0.2 million.
	Thereafter	above		$	0.6				50	%	50	%
													On December 2, 2013, we issued and sold 8,110,848 of our common units in a private placement. We received net proceeds of $235.1 million, after offering costs of $4.9 million.
	During the three months ended September 30, 2014, TLP declared and paid a distribution of $0.665 per unit. The noncontrolling interest owners received a total of $8.7 million from this distribution. Pursuant to the terms of the agreement related to our acquisition of TransMontaigne, we remitted the amount we received on this distribution on our general partner interest, incentive distribution rights, and limited partner interest to the former owners of TransMontaigne.
													Distributions
	In October 2014, TLP declared a distribution of $0.665 per unit, which was paid on November 7, 2014. The noncontrolling interest owners received a total of $8.7 million from this distribution.
													Our general partner has adopted a cash distribution policy that will require us to pay a quarterly distribution to the extent we have sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to the general partner and its affiliates, referred to as “available cash,” in the following manner:
	Equity-Based Incentive Compensation
													·                  First, 99.9% to the holders of common units and 0.1% to the general partner, until each common unit has received the specified minimum quarterly distribution, plus any arrearages from prior quarters.
	Our general partner has adopted a long-term incentive plan (“LTIP”), which allows for the issuance of equity-based compensation to employees and directors. Our general partner has granted certain restricted units to employees and directors, which will 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. No distributions will accrue to or be paid on the restricted units during the vesting period.
													·                  Second, 99.9% to the holders of subordinated units and 0.1% to the general partner, until each subordinated unit has received the specified minimum quarterly distribution.
	The following table summarizes the restricted unit activity during the six months ended September 30, 2014:
													·                  Third, 99.9% to all unitholders, pro rata, and 0.1% to the general partner.
	Unvested restricted units at March 31, 2014	1,311,100
	Units granted	333,903											The general partner will also receive, in addition to distributions on its 0.1% general partner interest, additional distributions based on the level of distributions paid to the limited partners. These distributions are referred to as “incentive distributions.”
	Units vested and issued	(438,009	)
	Units withheld for employee taxes	(231,194	)										The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 0.1% general partner interest, assume our general partner has contributed any additional capital necessary to maintain its 0.1% general partner interest and has not transferred its IDRs and there are no arrearages on common units.
	Units forfeited	(117,000	)
	Unvested restricted units at September 30, 2014	858,800																			Marginal Percentage Interest In
														Total Quarterly							Distributions
	The scheduled vesting of our unvested restricted units is summarized below:													Distribution per Unit							Unitholders		General Partner
													Minimum quarterly distribution						$ 0.337500		99.9	%	0.1	%
	Vesting Date	Number of Awards											First target distribution	above		$ 0.337500	up to		$ 0.388125		99.9	%	0.1	%
	July 1, 2015	334,800											Second target distribution	above		$ 0.388125	up to		$ 0.421875		86.9	%	13.1	%
	July 1, 2016	314,000											Third target distribution	above		$ 0.421875	up to		$ 0.506250		76.9	%	23.1	%
	July 1, 2017	178,500											Thereafter	above		$ 0.506250					51.9	%	48.1	%
	July 1, 2018	31,500
	Unvested restricted units at September 30, 2014	858,800											On May 5, 2011, we made a distribution of $3.9 million from available cash to our general partner and common unitholders at March 31, 2011.
	We record the expense for the first tranche of each award on a straight-line basis over the period beginning with the grant date of the awards and ending with the vesting date of the tranche. We record the expense for succeeding tranches over the period beginning with the vesting date of the previous tranche and ending with the vesting date of the tranche.												The following table summarizes the distributions declared subsequent to our IPO:
	At each balance sheet date, we adjust the cumulative expense recorded using the estimated fair value of the awards at the balance sheet date. We calculate the fair value of the awards using the closing price of our common units on the New York Stock Exchange on the balance sheet date, adjusted to reflect the fact that the holders of the unvested units are not entitled to distributions during the vesting period. We estimate the impact of the lack of distribution rights during the vesting period using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.																Amount			Amount Paid to			Amount Paid to
													Date Declared	Record Date		Date Paid	Per Unit			Limited Partners			General Partner
	We recorded expense related to restricted unit awards of $13.8 million and $3.2 million during the three months ended September 30, 2014 and 2013, respectively, and $21.7 million and $10.3 million during the six months ended September 30, 2014 and 2013, respectively. We estimate that the future expense we will record on the unvested awards at September 30, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of approximately 80,000 units. For purposes of this calculation, we used the closing price of our common units on September 30, 2014, which was $39.37.																			(in thousands)			(in thousands)
													July 25, 2011	August 3, 2011		August 12, 2011	$	0.1669		$	2,467		$	3
Year Ending March 31,												October 21, 2011	October 31, 2011		November 14, 2011	0.3375			4,990			5
2015 (six months)	$	6,343										January 24, 2012	February 3, 2012		February 14, 2012	0.35			7,735			10
2016	11,516											April 18, 2012	April 30, 2012		May 15, 2012	0.3625			9,165			10
2017	7,262											July 24, 2012	August 3, 2012		August 14, 2012	0.4125			13,574			134
2018	2,237											October 17, 2012	October 29, 2012		November 14, 2012	0.45			22,846			707
2019	249											January 24, 2013	February 4, 2013		February 14, 2013	0.4625			24,245			927
Total	$	27,607										April 25, 2013	May 6, 2013		May 15, 2013	0.4775			25,605			1,189
												July 25, 2013	August 5, 2013		August 14, 2013	0.4938			31,725			1,739
Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our condensed consolidated balance sheets (in thousands):												October 23, 2013	November 4, 2013		November 14, 2013	0.5113			35,908			2,491
												January 23, 2014	February 4, 20143		February 14, 2014	0.5313			42,150			4,283
Balance at March 31, 2014	$	10,012										April 24, 2014	May 5, 2014		May 15, 2014	0.5513			43,737			5,754
Expense recorded	21,659
Value of units vested and issued	(18,763		)
Taxes paid on behalf of participants	(9,901		)									Several of our business combination agreements contained provisions that temporarily limited the distributions to which the newly-issued units were entitled. The following table summarizes the number of equivalent units that were not eligible to receive a distribution on each of the record dates:
Balance at September 30, 2014	$	3,007
													Equivalent
The weighted-average fair value of the awards at September 30, 2014 was $35.16 per common unit, which was calculated as the closing price of the common units on September 30, 2014, adjusted to reflect the fact that the restricted units are not entitled to distributions during the vesting period. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.													Units Not
												Record Date	Eligible
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 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 will not be considered to be delivered under the LTIP. In addition, if 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, 2014, 7.1 million units remain available for issuance under the LTIP.												August 3, 2011	—
												October 31, 2011	4,000,000
												February 3, 2012	7,117,031
												April 30, 2012	3,932,031
												August 3, 2012	17,862,470
												October 29, 2012	516,978
												February 4, 2013	1,202,085
												May 6, 2013	—
												August 5, 2013	—
												November 4, 2013	979,886
												February 4, 2014	—
												May 5, 2014	—
												Equity-Based Incentive Compensation
												Our general partner has adopted a long-term incentive plan (“LTIP”) which allows for the issuance of equity-based compensation to employees and directors. The board of directors of our general partner has granted certain restricted units to employees and directors, which will 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. No distributions will accrue to or be paid on the restricted units during the vesting period.
												The following table summarizes the restricted unit activity during the years ended March 31, 2014 and 2013:
												Unvested restricted units at March 31, 2012	—
												Units granted	1,684,400
												Units vested and issued	(156,802	)
												Units withheld for employee taxes	(61,698	)
												Units forfeited	(21,000	)
												Unvested restricted units at March 31, 2013	1,444,900
												Units granted	494,000
												Units vested and issued	(296,269	)
												Units withheld for employee taxes	(122,531	)
												Units forfeited	(209,000	)
												Unvested restricted units at March 31, 2014	1,311,100
												The scheduled vesting of the awards is summarized below:
												Vesting Date	Number of Awards
												July 1, 2014	408,300
												January 1, 2015	4,000
												July 1, 2015	341,300
												January 1, 2016	4,000
												July 1, 2016	322,500
												January 1, 2017	4,000
												July 1, 2017	192,500
												January 1, 2018	4,000
												July 1, 2018	30,500
												Total unvested units at March 31, 2014	1,311,100
												We record the expense for each tranche on a straight-line basis over the period beginning with the vesting of the previous tranche and ending with the vesting of the tranche. We adjust the cumulative expense recorded through the reporting date using the estimated fair value of the awards at the reporting date. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth. We estimate that the future expense we will record on the unvested awards at March 31, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of 95,000 units. For purposes of this calculation, we have used the closing price of the common units on March 31, 2014, which was $37.53.
												Year Ending March 31,
												2015	$	14,393
												2016	11,279
												2017	7,429
												2018	2,310
												2019	229
												Total	$	35,640
												Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our consolidated balance sheets (in thousands):
												Balance at March 31, 2012	$	—
												Expense recorded	10,138
												Value of units vested and issued	(3,627		)
												Taxes paid on behalf of participants	(1,468		)
												Balance at March 31, 2013	5,043
												Expense recorded	17,804
												Value of units vested and issued	(9,085		)
												Taxes paid on behalf of participants	(3,750		)
												Balance at March 31, 2014	$	10,012
												The weighted-average fair value of the awards at March 31, 2014 was $33.78, which was calculated as the closing price of the common units on March 31, 2014, adjusted to reflect the fact that the restricted units are not entitled to distributions during the vesting period. The impact of the lack of distribution rights during the vesting period was estimated using the value of the most recent distribution and assumptions that a market participant might make about future distribution growth.
												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 and subordinated units. The maximum number of units deliverable under the plan automatically increases to 10% of the issued and outstanding common and subordinated 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, if 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 March 31, 2014, 6.2 million units remain available for issuance under the LTIP.

Fair_Value_of_Financial_Instru5

Fair Value of Financial Instruments	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Fair Value of Financial Instruments
Fair Value of Financial Instruments	Note 11 — Fair Value of Financial Instruments												Note 12 — 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.												Our cash and cash equivalents, accounts receivable, accounts payable, accrued expenses, and other current liabilities (excluding derivative instruments) are carried at amounts which reasonably approximate their fair values, due to their short-term nature. We believe the carrying amounts of our long-term debt instruments, including the Revolving Credit Facility and the Senior Notes, approximate their fair values, as we do not believe market conditions have changed materially since we entered into these debt agreements.
	Commodity Derivatives												Commodity Derivatives
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at September 30, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2014:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	48,632		$	(5,378	)					Level 1 measurements	$	4,990		$	(3,258	)
	Level 2 measurements		51,389			(38,280		)					Level 2 measurements	49,605			(43,303		)
			100,021			(43,658		)						54,595			(46,561		)
	Netting of counterparty contracts (1)		(4,635		)	4,635							Netting of counterparty contracts(1)	(4,347		)	4,347
	Cash collateral held		(13,704		)	—							Cash collateral provided or held	456			—
	Commodity derivatives on condensed consolidated balance sheet		$	81,682		$	(39,023	)					Commodity contracts reported on consolidated balance sheet	$	50,704		$	(42,214	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at March 31, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2013:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	4,990		$	(3,258	)					Level 1 measurements	$	947		$	(3,324	)
	Level 2 measurements		49,605			(43,303		)					Level 2 measurements	9,911			(13,280		)
			54,595			(46,561		)						10,858			(16,604		)
	Netting of counterparty contracts (1)		(4,347		)	4,347							Netting of counterparty contracts(1)	(3,503		)	3,503
	Net cash collateral provided		456			—							Cash collateral provided or held	(1,760		)	400
	Commodity derivatives on condensed consolidated balance sheet		$	50,704		$	(42,214	)					Commodity contracts reported on consolidated balance sheet	$	5,595		$	(12,701	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	Our commodity derivative assets and liabilities are reported in the following accounts on the condensed consolidated balance sheets:												The commodity derivative assets (liabilities) are reported in the following accounts on the consolidated balance sheets:
			September 30,			March 31,								March 31,
			2014			2014								2014			2013
			(in thousands)											(in thousands)
	Prepaid expenses and other current assets		$	81,682		$	50,704						Prepaid expenses and other current assets	$	50,704		$	5,551
	Accrued expenses and other payables		(39,023		)	(42,214		)					Other noncurrent assets	—			44
	Net commodity derivative asset		$	42,659		$	8,490						Accrued expenses and other payables	(42,214		)	(12,701		)
													Net asset (liability)	$	8,490		$	(7,106	)
	The following table summarizes our open commodity derivative contract positions at September 30, 2014 and March 31, 2014. We do not account for these derivatives as hedges.
													The following table sets forth our open commodity derivative contract positions at March 31, 2014 and 2013. We do not account for these derivatives as hedges.
					Total		Fair Value
					Notional		of						Contracts	Settlement Period		Total		Fair Value
					Units		Net Assets									Notional		of Net Assets
	Contracts		Settlement Period		(Barrels)		(Liabilities)									Units		(Liabilities)
					(in thousands)											(Barrels)
	At September 30, 2014 -															(in thousands)
	Cross-commodity (1)		October 2014 – March 2015		(12	)	$	(1,283	)				At March 31, 2014 -
	Crude oil fixed-price (2)		October 2014 – December 2015		(1,638	)	9,380						Cross-commodity (1)	April 2014 – March 2015		140		$	(1,876	)
	Crude oil index (3)		October 2014 – July 2015		2,195		4,397						Crude oil fixed-price (2)	April 2014 – March 2015		(1,600	)	(2,796		)
	Propane fixed-price (4)		October 2014 – March 2015		1,238		53						Crude oil index (3)	April 2014 – December 2015		3,598		6,099
	Refined products fixed-price (5)		October 2014 – July 2015		(4,475	)	38,712						Propane fixed-price (4)	April 2014 – March 2015		60		1,753
	Renewable products fixed-price (6)		October 2014 – December 2015		(14	)	5,104						Refined products fixed-price (5)	April 2014 – July 2014		732		560
							56,363						Renewable products fixed-price (6)	April 2014 – July 2014		106		4,084
	Net cash collateral held						(13,704		)				Other	April 2014		—		210
	Net commodity derivatives on condensed consolidated balance sheet						$	42,659										8,034
													Net cash collateral provided					456
	At March 31, 2014 -												Net value of commodity derivatives on consolidated balance sheet					$	8,490
	Cross-commodity (1)		April 2014 – March 2015		140		$	(1,876	)
	Crude oil fixed-price (2)		April 2014 – March 2015		(1,600	)	(2,796		)				At March 31, 2013 -
	Crude oil index (3)		April 2014 – December 2015		3,598		6,099						Cross-commodity (1)	April 2013 - March 2014		430		$	(10,208	)
	Propane fixed-price (4)		April 2014 – March 2015		60		1,753						Crude oil fixed-price (2)	April 2013 - March 2014		(144	)	1,033
	Refined products fixed-price (5)		April 2014 – July 2014		732		560						Crude oil index (3)	April 2013 - June 2014		(91	)	153
	Renewable products fixed-price (6)		April 2014 – July 2014		106		4,084						Propane fixed-price (4)	April 2013 - March 2014		(282	)	3,197
	Other		April 2014		—		210						Other	May 2013 - June 2013		8		79
							8,034											(5,746		)
	Net cash collateral provided						456						Net cash collateral held					(1,360		)
	Net commodity derivatives on condensed consolidated balance sheet						$	8,490					Net value of commodity derivatives on consolidated balance sheet					$	(7,106	)
	(1)     Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price.												(1)         Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as economic hedges against the risk of one commodity price moving relative to another commodity price.
	(2)     Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.												(2)         Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
(3)     Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.												(3)         Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
(4)     Propane fixed-price — Our liquids segment routinely purchases propane inventory during the warmer months and stores the propane inventory for sale during the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.												(4)         Propane fixed-price — Our liquids segment routinely purchases inventory during the warmer months and stores the inventory for sale in the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
(5)     Refined products fixed-price — Our refined products and renewables segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.												(5)         Refined products fixed-price — Our refined products segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
(6)     Renewable products fixed-price — Our refined products and renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.												(6)         Renewable products fixed-price — Our renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
We recorded the following net gains (losses) from our commodity derivatives to cost of sales:												We recorded the following net gains (losses) from our commodity derivatives to cost of sales:
Three Months Ended						Six Months Ended						Year Ended March 31,
September 30,						September 30,						2014	$	(43,655	)
2014			2013			2014			2013			2013	(4,381		)
(in thousands)												2012	5,676
$	55,981		$	(10,672	)	$	38,496		$	(17,881	)
												Credit Risk
Credit Risk
												We maintain credit policies with regard to our counterparties on the derivative financial instruments 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 standardized agreements, which allow for netting of positive and negative exposure associated with a single counterparty.
We maintain credit policies with regard to our counterparties on the derivative financial instruments 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 standardized agreements, which allow for netting of positive and negative exposure associated with a single counterparty.
												We may enter into industry standard master netting agreements and may enter into cash collateral agreements requiring the counterparty to deposit funds into a brokerage margin account. The netting agreements reduce our credit risk by providing for net settlement of any offsetting positive and negative exposures with counterparties. The cash collateral agreements reduce the level of our net counterparty credit risk because the amount of collateral represents additional funds that we may access to net settle positions due us, and the amount of collateral adjusts each day in response to changes in the market value of counterparty derivatives.
We may enter into industry standard master netting agreements and may enter into cash collateral agreements requiring the counterparty to deposit funds into a brokerage margin account. The netting agreements reduce our credit risk by providing for net settlement of any offsetting positive and negative exposures with counterparties. The cash collateral agreements reduce the level of our net counterparty credit risk because the amount of collateral represents additional funds that we may access to net settle positions due us, and the amount of collateral adjusts each day in response to changes in the market value of counterparty derivatives.
												Our counterparties consist primarily of financial institutions and energy companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
Our counterparties consist primarily of financial institutions and energy companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
												As is customary in the crude oil industry, we generally receive payment from customers on a monthly basis. As a result, receivables from individual customers in our crude oil logistics are typically higher than the receivables from customers of our other segments.
As is customary in the crude oil industry, we generally receive payment from customers for sales of crude oil on a monthly basis. As a result, receivables from individual customers in our crude oil logistics segment are generally higher than the receivables from customers in our other segments.
												Failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our consolidated statements of financial position and recognized in our net income.
Failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our condensed consolidated balance sheets and recognized in our net income.
												Interest Rate Risk
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 March 31, 2014, we have $922.0 million of outstanding borrowings under our Revolving Credit Facility at a rate of 1.98%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $1.2 million on the $922.0 million of outstanding borrowings on the revolving credit facility at March 31, 2014.
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, 2014, we had $1.1 billion of outstanding borrowings under our Revolving Credit Facility at a rate of 1.91%. A change in interest rates of 0.125% would result in an increase or decrease of our annual interest expense of $1.3 million, based on borrowings outstanding at September 30, 2014.
The TLP Credit Facility is variable-rate debt with interest rates that are generally indexed to bank prime or LIBOR interest rates. At September 30, 2014, TLP had $252.0 million of outstanding borrowings under the TLP Credit Facility at a rate of 2.66%. A change in interest rates of 0.125% would result in an increase or decrease in TLP’s annual interest expense of $0.3 million, based on borrowings outstanding at September 30, 2014.
Fair Value of Notes
The following table provides estimates of the fair values of our fixed-rate notes at September 30, 2014 (in thousands):
5.125% Notes due 2019		$	390,000
6.875% Notes due 2021		475,000
6.650% Notes due 2022		275,000
For the 2019 Notes and the 2021 Notes, the fair value estimates were developed by reference to broker quotes.  These estimates would be classified as Level 2 in the fair value hierarchy. For the 2022 Notes, the estimate was developed using observed yields on publicly-traded notes issued by other entities, 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).  These estimates of fair value would be classified as Level 3 in the fair value hierarchy.

Segments1

Segments	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Segments
Segments	Note 12 — Segments													Note 13 — Segments
	Our reportable segments are based on the way in which our management structure is organized. Certain financial data related to our segments is shown below. Transactions between segments are recorded based on prices negotiated between the segments.													Our reportable segments are based on the way in which our management structure is organized. Certain financial data related to our segments is shown below. Transactions between segments are recorded based on prices negotiated between the segments.
	Our crude oil logistics segment sells crude oil and provides crude oil transportation services to wholesalers, refiners, and producers. Our water solutions segment provides services for the treatment and disposal of wastewater generated from crude oil and natural gas production, and generates revenue from the sale of recycled water and recovered hydrocarbons. Our liquids segment supplies propane, butane, and other products, and provides natural gas liquids transportation, terminaling, and storage services to retailers, wholesalers, and refiners. Our retail propane segment sells propane and distillates to end users consisting of residential, agricultural, commercial, and industrial customers, and to certain re-sellers. Our retail propane segment consists of two divisions, which are organized based on the location of the operations. Our refined products and renewables segment provides integrated terminaling, storage, transportation, marketing, and related services for companies engaged in the trading, distribution and marketing of refined petroleum products, ethanol, and biodiesel. This segment began with our December 2013 acquisition of Gavilon Energy and expanded with our July 2014 acquisition of TransMontaigne.													Our crude oil logistics segment sells crude oil and provides crude oil transportation services to wholesalers, refiners, and producers. Our water solutions segment provides services for the transportation, treatment, and disposal of wastewater generated from crude oil and natural gas production, and generates revenue from the sale of recycled wastewater and recovered hydrocarbons. Our liquids segment supplies propane, butane, and other products, and provides natural gas liquids transportation, terminaling, and storage services to retailers, wholesalers, and refiners. Our retail propane segment sells propane and distillates to end users consisting of residential, agricultural, commercial, and industrial customers, and to certain re-sellers. Our retail propane segment consists of two divisions, which are organized based on the location of the operations.
	Items labeled “corporate and other” in the table below include the operations of a compressor leasing business that we sold in February 2014 and certain natural gas marketing operations that we acquired in our December 2013 acquisition of Gavilon Energy and wound down during fiscal year 2014. The “corporate and other” category also includes certain corporate expenses that are incurred and are not allocated to the reportable segments. This data is included to reconcile the data for the reportable segments to data in our condensed consolidated financial statements.													We also operate a refined products marketing business, which purchases gasoline and diesel fuel from suppliers and typically sells these products in back-to-back contracts to customers at a nationwide network of third-party owned terminaling and storage facilities. We also operate a renewables business, which purchases ethanol primarily at production facilities, and transports the ethanol for sale at various locations to refiners and blenders, and purchases biodiesel from production facilities in the Midwest and in Houston, Texas, and transports the product using leased railcars for sale to refiners and blenders. These businesses were acquired in our December 2013 acquisition of Gavilon Energy.
		Three Months Ended						Six Months Ended						Items labeled “corporate and other” in the table below include the operations of a compressor leasing business that we acquired in our June 2012 merger with High Sierra and sold in February 2014, and the natural gas marketing operations that we acquired in our December 2013 acquisition of Gavilon Energy and began winding down during fiscal 2014. The “corporate and other” category also includes certain corporate expenses that are incurred and are not allocated to the reportable segments. This data is included to reconcile the data for the reportable segments to data in our consolidated financial statements.
		September 30,						September 30,
		2014			2013			2014			2013			Certain information related to the results of operations of each segment is shown in the tables below:
		(in thousands)
	Revenues:														Year Ended March 31,
	Crude oil logistics -														2014			2013			2012
	Crude oil sales	$	2,108,117		$	1,013,061		$	4,035,061		$	1,941,595			(in thousands)
	Crude oil transportation and other	13,082			9,794			25,196			19,729			Revenues:
	Water solutions -													Crude oil logistics -
	Water treatment and disposal	47,572			28,823			89,288			47,511			Crude oil sales	$	4,559,923		$	2,322,706		$	—
	Water transportation	5,147			5,367			10,745			7,192			Crude oil transportation and other	36,469			16,442			—
	Liquids -													Water solutions -
	Propane sales	240,433			191,437			462,879			315,274			Water treatment and disposal	125,788			54,334			—
	Other product sales	306,625			308,606			594,984			558,459			Water transportation	17,312			7,893			—
	Other revenues	6,814			9,250			12,530			18,114			Liquids -
	Retail propane -													Propane sales	1,632,948			841,448			923,022
	Propane sales	48,552			40,651			100,578			87,342			Other product sales	1,231,965			858,276			251,627
	Distillate sales	11,530			10,562			30,225			28,431			Other revenues	31,062			33,954			2,462
	Other revenues	8,276			8,198			15,457			15,898			Retail propane -
	Refined products and renewables -													Propane sales	388,225			288,410			175,417
	Refined products sales	2,489,795			—			3,476,018			—			Distillate sales	127,672			106,192			6,547
	Renewables sales	117,425			—			248,699			—			Other revenues	35,918			35,856			17,370
	Corporate and other	1,333			1,485			2,794			2,959			Refined products	1,180,895			—			—
	Elimination of intersegment sales	(24,175		)	(33,297		)	(75,314		)	(62,610		)	Renewables	176,781			—			—
	Total revenues	$	5,380,526		$	1,593,937		$	9,029,140		$	2,979,894		Corporate and other	437,713			4,233			—
														Eliminations of intersegment sales	(283,397		)	(151,977		)	(65,972		)
	Depreciation and Amortization:													Total revenues	$	9,699,274		$	4,417,767		$	1,310,473
	Crude oil logistics	$	9,240		$	3,330		$	18,971		$	8,014
	Water solutions	17,573			11,438			34,665			18,794				Year Ended March 31,
	Liquids	3,384			2,672			6,585			5,376				2014			2013			2012
	Retail propane	7,684			6,871			15,255			14,111				(in thousands)
	Refined products and renewables	11,917			—			12,761			—			Depreciation and amortization:
	Corporate and other	301			750			1,237			1,490			Crude oil logistics	$	22,111		$	9,176		$	—
	Total depreciation and amortization	$	50,099		$	25,061		$	89,474		$	47,785		Water solutions	55,105			20,923			—
														Liquids	11,018			11,085			3,661
	Operating Income (Loss):													Retail propane	28,878			25,496			11,450
	Crude oil logistics	$	38		$	5,884		$	1,501		$	12,493		Refined products	109			—			—
	Water solutions	14,792			2,913			13,885			5,956			Renewables	516			—			—
	Liquids	10,929			14,605			10,016			12,490			Corporate and other	3,017			2,173			—
	Retail propane	(3,062		)	(4,520		)	(4,648		)	(6,024		)	Total depreciation and amortization	$	120,754		$	68,853		$	15,111
	Refined products and renewables	8,822			—			7,567			—
	Corporate and other	(23,749		)	(8,937		)	(41,106		)	(22,312		)		Year Ended March 31,
	Total operating income (loss)	$	7,770		$	9,945		$	(12,785	)	$	2,603			2014			2013			2012
															(in thousands)
	The following table summarizes additions to property, plant and equipment for each segment. This information has been prepared on the accrual basis, and includes property, plant and equipment acquired in acquisitions.													Operating income (loss):
														Crude oil logistics	$	678		$	34,236		$	—
		Three Months Ended						Six Months Ended						Water solutions	10,317			8,576			—
		September 30,						September 30,						Liquids	71,888			30,336			9,735
		2014			2013			2014			2013			Retail propane	61,285			46,869			9,616
		(in thousands)												Refined products	4,080			—			—
	Additions to property, plant and equipment:													Renewables	2,434			—			—
	Crude oil logistics	$	39,464		$	31,336		$	81,413		$	35,462		Corporate and other	(44,117		)	(32,710		)	(4,321		)
	Water solutions	40,610			62,473			48,072			70,182			Total operating income	$	106,565		$	87,307		$	15,030
	Liquids	1,911			13,209			3,070			28,316
	Retail propane	9,567			4,546			12,411			11,492			The table below shows additions to property, plant and equipment for each segment. This information has been prepared on the accrual basis, and includes property, plant and equipment acquired in acquisitions.
	Refined products and renewables	512,281			—			512,281			—
	Corporate and other	1,809			217			3,262			846				Year Ended March 31,
	Total	$	605,642		$	111,781		$	660,509		$	146,298			2014			2013			2012
															(in thousands)
	The following tables summarize long-lived assets (consisting of net property, plant and equipment, net intangible assets, and goodwill) and total assets by segment:													Additions to property, plant and equipment, including acquisitions (accrual basis):
													Crude oil logistics	$	204,642		$	89,860		$	—
	September 30,			March 31,									Water solutions	100,877			137,116			—
	2014			2014									Liquids	52,560			15,129			50,276
	(in thousands)												Retail propane	24,430			66,933			150,181
Total assets:													Refined products	719			—			—
Crude oil logistics	$	2,079,380		$	1,723,812								Renewables	519			—			—
Water solutions	964,336			875,714									Corporate and other	7,242			17,858			—
Liquids	756,133			577,795									Total	$	390,989		$	326,896		$	200,457
Retail propane	506,958			541,832
Refined products and renewables	2,183,674			303,230									The following tables show long-lived assets (consisting of property, plant and equipment, intangible assets, and goodwill) and total assets by segment:
Corporate and other	61,198			144,840
Total	$	6,551,679		$	4,167,223									March 31,
																	2013
Long-lived assets, net:														2014			(Note 2)
Crude oil logistics	$	996,615		$	980,978									(in thousands)
Water solutions	910,467			848,479									Total assets:
Liquids	271,567			274,846									Crude oil logistics	$	1,723,812		$	801,351
Retail propane	436,621			438,324									Water solutions	875,714			466,412
Refined products and renewables	772,916			60,720									Liquids	577,795			474,141
Corporate and other	53,705			47,961									Retail propane	541,832			513,301
Total	$	3,441,891		$	2,651,308								Refined products	157,581			—
													Renewables	145,649			—
													Corporate and other	144,840			36,413
													Total	$	4,167,223		$	2,291,618
													Long-lived assets, net:
													Crude oil logistics	$	980,978		$	357,230
													Water solutions	848,479			453,909
													Liquids	274,846			238,192
													Retail propane	438,324			441,762
													Refined products	27,017			—
													Renewables	33,703			—
													Corporate and other	47,961			31,996
													Total	$	2,651,308		$	1,523,089

Transactions_with_Affiliates1

Transactions with Affiliates	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Transactions with Affiliates
Transactions with Affiliates	Note 13 — Transactions with Affiliates									Note 15 — Transactions with Affiliates
	SemGroup Corporation (“SemGroup”) holds ownership interests in us and in our general partner. We sell product to and purchase product from SemGroup, and these transactions are included within revenues and cost of sales in our condensed consolidated statements of operations. We also lease crude oil storage from SemGroup.									Since our business combination with SemStream on November 1, 2011, SemGroup Corporation (“SemGroup”) has held ownership interests in us and in our general partner, and has the right to appoint two members to the board of directors of our general partner. Subsequent to November 1, 2011, we have sold product to and purchased product from affiliates of SemGroup. These transactions are included within revenues and cost of sales in our consolidated statements of operations.
	We purchase ethanol from one of our equity method investees. These transactions are reported within cost of sales in our condensed consolidated statements of operations.									Certain members of our management own interests in entities with which we have purchased products and services from and have sold products and services. The majority of these purchases represent crude oil purchases and are reported within cost of sales in our consolidated statements of operations, although $8.2 million of these transactions during the year ended March 31, 2014 represented capital expenditures and were recorded as increases to property, plant and equipment. The majority of these sales represent sales of crude oil and have been recorded within revenues in our consolidated statement of operations.
	Certain members of our management own interests in entities from which we have purchased products and services and to which we have sold products and services to. The majority of these purchases represented crude oil purchases and are reported within cost of sales in our condensed consolidated statements of operations, although $5.8 million of these transactions during the six months ended September 30, 2014 represented capital expenditures and were recorded as increases to property, plant and equipment. The majority of these sales represented crude oil sales and are reported within revenues in our condensed consolidated statements of operations.									These transactions are summarized in the table below:
	The above transactions are summarized in the following table:										Year Ended March 31,
											2014		2013		2012
		Three Months Ended				Six Months Ended					(in thousands)
		September 30,				September 30,				Sales to SemGroup	$	306,780	$	32,431	$	29,200
		2014		2013		2014		2013		Purchases from SemGroup	445,951		60,425		23,800
		(in thousands)								Sales to entities affiliated with management	110,824		16,828		—
	Sales to SemGroup	$	43,427	$	3,780	$	117,233	$	3,780	Purchases from entities affiliated with management	120,038		60,942		—
	Purchases from SemGroup	45,730		28,377		118,997		47,916
	Purchases from equity method investees	34,689		—		70,965		—
	Sales to equity method investees	9,131		—		9,131		—		Receivables from affiliates consist of the following:
	Sales to entities affiliated with management	1,706		58,769		1,854		109,872
	Purchases from entities affiliated with management	3,845		48,522		6,984		56,346			March 31,
											2014		2013
											(in thousands)
	Receivables from affiliates consist of the following:									Receivables from entities affiliated with management	$	142	$	22,883
										Receivables from SemGroup	7,303		—
		September 30,		March 31,							$	7,445	$	22,883
		2014		2014
		(in thousands)								Payables to affiliates consist of the following:
	Receivables from SemGroup	$	39,331	$	7,303
	Receivables from entities affiliated with management	1,705		142							March 31,
	Receivables from equity method investees	670		—							2014		2013
	Total	$	41,706	$	7,445						(in thousands)
										Payables to SemGroup	$	76,192	$	4,601
	Payables to affiliates consist of the following:									Payables to entities affiliated with management	654		2,299
											$	76,846	$	6,900
		September 30,		March 31,
		2014		2014						We completed a merger with High Sierra Energy, LP and High Sierra Energy GP, LLC in June 2012. We paid $91.8 million of cash, net of $5.0 million of cash acquired, and issued 18,018,468 common units to acquire High Sierra Energy, LP. We also paid $97.4 million of High Sierra Energy, LP’s long-term debt and other obligations. Our general partner acquired High Sierra Energy GP, LLC by paying $50.0 million of cash and issuing equity. Our general partner then contributed its ownership interests in High Sierra Energy GP, LLC to us, in return for which we paid our general partner $50.0 million of cash and issued 2,685,042 common units to our general partner.
		(in thousands)
	Payables to SemGroup	$	44,015	$	27,738					During the year ended March 31, 2014, we completed the acquisition of a crude oil logistics business owned by an employee. We paid $11.0 million of cash for this acquisition. During the year ended March 31, 2013, we completed two business combinations with entities in which members of our management owned interests. We paid $14.0 million of cash (net of cash acquired) on a combined basis for these two acquisitions. We also paid $5.0 million under a non-compete agreement to an employee.
	Payables to equity method investees	39,549		48,454
	Payables to entities affiliated with management	1,743		654
	Total	$	85,307	$	76,846

Condensed_Consolidating_Guaran6

Condensed Consolidating Guarantor and Non-Guarantor Financial Information	6 Months Ended																			12 Months Ended
	Sep. 30, 2014																			Mar. 31, 2014
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Condensed Consolidating Guarantor and Non-Guarantor Financial Information	Note 14 — Condensed Consolidating Guarantor and Non-Guarantor Financial Information																			Note 17 — 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 the 2021 Notes (described in Note 7). 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, NGL Energy Finance Corp. (which, along with NGL Energy Partners LP, is a co-issuer of the 2019 Notes and 2021 Notes), the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis in the tables below.																			Certain of our wholly-owned subsidiaries have, jointly and severally, fully and unconditionally guaranteed the Unsecured Notes (described in 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, NGL Energy Finance Corp. (which, along with NGL Energy Partners LP, is a co-issuer of the Unsecured Notes), the guarantor subsidiaries on a combined basis, and the non-guarantor subsidiaries on a combined basis 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.																			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 Unsecured Notes. Such changes have been given retrospective application in the tables below.
	There are no significant restrictions upon the ability of the parent or any of the guarantor subsidiaries to obtain funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.																			There are no significant restrictions upon the ability of the parent or any of the guarantor subsidiaries to obtain funds from their respective subsidiaries by dividend or loan. None of the assets of the guarantor subsidiaries represent restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act.
	For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, not a business segment basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to or from consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating cash flow tables below.																			For purposes of the tables below, (i) the condensed consolidating financial information is presented on a legal entity basis, not a business segment basis, (ii) investments in consolidated subsidiaries are accounted for as equity method investments, and (iii) contributions, distributions, and advances to or from consolidated entities are reported on a net basis within net changes in advances with consolidated entities in the condensed consolidating cash flow tables below.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Balance Sheet																			Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		September 30, 2014																			March 31, 2014
		NGL Energy			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
		Partners LP																			Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	ASSETS																			ASSETS
	CURRENT ASSETS:																			CURRENT ASSETS:
	Cash and cash equivalents	$	2,841		$	—		$	7,823		$	1,159		$	—		$	11,823		Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			1,419,442			13,675			—			1,433,117			Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904
	Accounts receivable - affiliates	—			—			41,035			671			—			41,706			Accounts receivable - affiliates	—			—			7,445			—			—			7,445
	Inventories	—			—			937,814			3,775			—			941,589			Inventories	—			—			306,434			3,726			—			310,160
	Prepaid expenses and other current assets	—			—			155,332			1,486			—			156,818			Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	2,841			—			2,561,446			20,766			—			2,585,053			Total current assets	1,181			—			1,290,690			17,428			—			1,309,299
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			863,694			569,619			—			1,433,313			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346
	GOODWILL	—			—			1,139,374			31,116			—			1,170,490			GOODWILL	—			—			1,105,008			1,998			—			1,107,006
	INTANGIBLE ASSETS, net of accumulated amortization	1,307			17,619			778,960			40,202			—			838,088			INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956
	INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			214,234			268,410			—			482,644			INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821
	NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893			849,526			(1,026,605		)	(71,814		)	—			—			NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—
	INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573			—			10,470			—			(1,754,043		)	—			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
	OTHER NONCURRENT ASSETS	—			—			40,035			2,056			—			42,091			OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795
	Total assets	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679		Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	LIABILITIES AND EQUITY																			LIABILITIES AND EQUITY
	CURRENT LIABILITIES:																			CURRENT LIABILITIES:
	Accounts payable - trade	$	—		$	—		$	1,333,780		$	11,244		$	—		$	1,345,024		Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211
	Accounts payable - affiliates	—			—			85,237			70			—			85,307			Accounts payable - affiliates	—			—			73,703			3,143			—			76,846
	Accrued expenses and other payables	554			19,021			186,226			12,681			—			218,482			Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690
	Advance payments received from customers	—			—			105,597			508			—			106,105			Advance payments received from customers	—			—			29,891			74			—			29,965
	Current maturities of long-term debt	—			—			5,004			58			—			5,062			Current maturities of long-term debt	—			—			7,058			22			—			7,080
	Total current liabilities	554			19,021			1,715,844			24,561			—			1,759,980			Total current liabilities	554			14,266			961,827			19,145			—			995,792
	LONG-TERM DEBT, net of current maturities	250,000			850,000			1,085,155			252,196			—			2,437,351			LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834
	OTHER NONCURRENT LIABILITIES	—			—			35,160			4,358			—			39,518			OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744
																				EQUITY
	EQUITY																			Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815
	Partners’ equity (deficit)	1,746,060			(1,876		)	1,745,450			579,312			(2,322,813		)	1,746,133			Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
	Accumulated other comprehensive loss	—			—			(1		)	(72		)	—			(73		)	Noncontrolling interests	—			—			—			—			5,274			5,274
	Noncontrolling interests	—			—			—			—			568,770			568,770			Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
	Total equity (deficit)	1,746,060			(1,876		)	1,745,449			579,240			(1,754,043		)	2,314,830			Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	Total liabilities and equity	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679
																				(1)   The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)         The parent is a co-issuer of the 2019 Notes and 2021 Notes that are included in the NGL Energy Finance Corp. column.																			NGL ENERGY PARTNERS LP
																				Condensed Consolidating Balance Sheet
	NGL ENERGY PARTNERS LP																			(U.S. Dollars in Thousands)
	Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																				March 31, 2013
																					NGL Energy
		March 31, 2014																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		NGL Energy																			(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						ASSETS
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			CURRENT ASSETS:
	ASSETS																			Cash and cash equivalents	$	—		$	11,206		$	355		$	—		$	11,561
	CURRENT ASSETS:																			Accounts receivable - trade, net of allowance for doubtful accounts	—			561,560			1,197			—			562,757
	Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440		Accounts receivable - affiliates	—			22,883			—			—			22,883
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904			Inventories	—			126,024			871			—			126,895
	Accounts receivable - affiliates	—			—			7,445			—			—			7,445			Prepaid expenses and other current assets	—			37,784			107			—			37,891
	Inventories	—			—			306,434			3,726			—			310,160			Total current assets	—			759,457			2,530			—			761,987
	Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	1,181			—			1,290,690			17,428			—			1,309,299			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			497,743			28,694			—			526,437
																			GOODWILL	—			553,222			1,998			—			555,220
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346			INTANGIBLE ASSETS, net of accumulated amortization	717			439,365			1,350			—			441,432
GOODWILL	—			—			1,105,008			1,998			—			1,107,006			NET INTERCOMPANY RECEIVABLES (PAYABLES)	237,736			(233,294		)	(4,442		)	—			—
INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	895,779			20,371			—			(916,150		)	—
INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821			OTHER NONCURRENT ASSETS	—			6,542			—			—			6,542
NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—			Total assets	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795			LIABILITIES AND EQUITY
Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		CURRENT LIABILITIES:
																			Accounts payable - trade	$	—		$	534,164		$	1,891		$	—		$	536,055
LIABILITIES AND EQUITY																			Accounts payable - affiliates	—			6,900			—			—			6,900
CURRENT LIABILITIES:																			Accrued expenses and other payables	554			83,001			2,051			—			85,606
Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211		Advance payments received from customers	—			22,364			8			—			22,372
Accounts payable - affiliates	—			—			73,703			3,143			—			76,846			Current maturities of long-term debt	—			8,610			16			—			8,626
Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690			Total current liabilities	554			655,039			3,966			—			659,559
Advance payments received from customers	—			—			29,891			74			—			29,965
Current maturities of long-term debt	—			—			7,058			22			—			7,080			LONG-TERM DEBT, net of current maturities	250,000			490,433			3			—			740,436
Total current liabilities	554			14,266			961,827			19,145			—			995,792			OTHER NONCURRENT LIABILITIES	—			2,155			50			—			2,205
																			EQUITY
LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834			Partners’ equity	883,678			895,779			26,087			(921,890		)	883,654
OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744			Accumulated other comprehensive income	—			—			24			—			24
																			Noncontrolling interests	—			—			—			5,740			5,740
EQUITY																			Total equity	883,678			895,779			26,111			(916,150		)	889,418
Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815			Total liabilities and equity	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
Noncontrolling interests	—			—			—			—			5,274			5,274			NGL ENERGY PARTNERS LP
Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853			Condensed Consolidating Statement of Operations
Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		(U.S. Dollars in Thousands)
																				Year Ended March 31, 2014
(1)     The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.																				NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
NGL ENERGY PARTNERS LP																				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)																			REVENUES	$	—		$	—		$	9,560,124		$	139,519		$	(369	)	$	9,699,274
	Three Months Ended September 30, 2014																		COST OF SALES	—			—			9,011,011			122,057			(369		)	9,132,699
	NGL Energy
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						OPERATING COSTS AND EXPENSES:
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			Operating	—			—			253,214			6,182			—			259,396
																			General and administrative	—			—			77,756			2,104			—			79,860
REVENUES	$	—		$	—		$	5,325,186		$	55,364		$	(24	)	$	5,380,526		Depreciation and amortization	—			—			117,573			3,181			—			120,754
COST OF SALES	—			—			5,161,935			17,554			(24		)	5,179,465			Operating Income	—			—			100,570			5,995			—			106,565
OPERATING COSTS AND EXPENSES:																			OTHER INCOME (EXPENSE):
Operating	—			—			84,300			17,253			—			101,553			Earnings from unconsolidated entities	—			—			1,898			—			—			1,898
General and administrative	—			—			36,360			5,279			—			41,639			Interest expense	(16,818		)	(15,000		)	(27,031		)	(51		)	46			(58,854		)
Depreciation and amortization	—			—			38,999			11,100			—			50,099			Other, net	—			—			202			(70		)	(46		)	86
Operating Income	—			—			3,592			4,178			—			7,770			Income (Loss) Before Income Taxes	(16,818		)	(15,000		)	75,639			5,874			—			49,695
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			—			(937		)	—			—			(937		)
Earnings of unconsolidated entities	—			—			2,310			1,387			—			3,697
Interest expense	(4,067		)	(13,134		)	(9,956		)	(1,506		)	12			(28,651		)	EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	64,473			—			4,771			—			(69,244		)	—
Other, net	—			—			(524		)	(81		)	(12		)	(617		)
																			Net Income (Loss)	47,655			(15,000		)	79,473			5,874			(69,244		)	48,758
Income (Loss) Before Income Taxes	(4,067		)	(13,134		)	(4,578		)	3,978			—			(17,801		)
																			NET INCOME ALLOCATED TO GENERAL PARTNER													(14,148		)	(14,148		)
INCOME TAX (PROVISION) BENEFIT	—			—			1,951			(29		)	—			1,922
																			NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(1,103		)	(1,103		)
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(15,157		)	—			604			—			14,553			—
																			NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(84,495	)	$	33,507
Net Income (Loss)	(19,224		)	(13,134		)	(2,023		)	3,949			14,553			(15,879		)
																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(11,056		)	(11,056		)
																			NGL ENERGY PARTNERS LP
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,345		)	(3,345		)	Condensed Consolidating Statement of Operations
																			(U.S. Dollars in Thousands)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	152		$	(30,280	)
																				Year Ended March 31, 2013
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																				NGL Energy
																				Partners LP			Guarantor			Non-Guarantor			Consolidating
NGL ENERGY PARTNERS LP																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)																			REVENUES	$	—		$	4,409,198		$	8,878		$	(309	)	$	4,417,767
	Three Months Ended September 30, 2013																		COST OF SALES	—			4,038,251			1,168			(309		)	4,039,110
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor			Consolidating									OPERATING COSTS AND EXPENSES:
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Operating	—			164,944			4,855			—			169,799
																			General and administrative	—			52,461			237			—			52,698
REVENUES	$	—		$	1,546,226		$	47,735		$	(24	)	$	1,593,937					Depreciation and amortization	—			66,916			1,937			—			68,853
COST OF SALES	—			1,445,442			43,432			(24		)	1,488,850						Operating Income	—			86,626			681			—			87,307
OPERATING COSTS AND EXPENSES:																			OTHER INCOME (EXPENSE):
Operating	—			52,979			2,790			—			55,769						Interest expense	(13,041		)	(19,951		)	(48		)	46			(32,994		)
General and administrative	—			14,089			223			—			14,312						Loss on early extinguishment of debt	—			(5,769		)	—			—			(5,769		)
Depreciation and amortization	—			23,970			1,091			—			25,061						Other, net	—			1,666			(99		)	(46		)	1,521
Operating Income	—			9,746			199			—			9,945						Income (Loss) Before Income Taxes	(13,041		)	62,572			534			—			50,065
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			(1,875		)	—			—			(1,875		)
Interest expense	(4,179		)	(6,880		)	(13		)	12			(11,060		)
Other, net	—			528			(97		)	(12		)	419						EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	60,981			284			—			(61,265		)	—
Income (Loss) Before Income Taxes	(4,179		)	3,394			89			—			(696		)				Net Income	47,940			60,981			534			(61,265		)	48,190
INCOME TAX PROVISION	—			(236		)	—			—			(236		)				NET INCOME ALLOCATED TO GENERAL PARTNER										(2,917		)	(2,917		)
EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	3,238			80			—			(3,318		)	—						NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(250		)	(250		)
Net Income (Loss)	(941		)	3,238			89			(3,318		)	(932		)				NET INCOME ALLOCATED TO LIMITED PARTNERS	$	47,940		$	60,981		$	534		$	(64,432	)	$	45,023
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(2,451		)	(2,451		)				NGL ENERGY PARTNERS LP
																			Condensed Consolidating Statement of Operations
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(9		)	(9		)				(U.S. Dollars in Thousands)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(941	)	$	3,238		$	89		$	(5,778	)	$	(3,392	)					Year Ended March 31, 2012
																				NGL Energy
NGL ENERGY PARTNERS LP																				Partners LP			Guarantor			Non-Guarantor			Consolidating
Condensed Consolidating Statement of Operations																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
(U.S. Dollars in Thousands)
																			REVENUES	$	—		$	1,310,473		$	225		$	(225	)	$	1,310,473
	Six Months Ended September 30, 2014
	NGL Energy																		COST OF SALES	—			1,217,248			—			(225		)	1,217,023
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			OPERATING COSTS AND EXPENSES:
																			Operating	—			47,162			138			—			47,300
REVENUES	$	—		$	—		$	8,952,772		$	76,421		$	(53	)	$	9,029,140		General and administrative	—			15,823			186			—			16,009
																			Depreciation and amortization	—			14,964			147			—			15,111
COST OF SALES	—			—			8,676,881			36,690			(53		)	8,713,518
																			Operating Income (Loss)	—			15,276			(246		)	—			15,030
OPERATING COSTS AND EXPENSES:
Operating	—			—			150,919			18,502			—			169,421			OTHER INCOME (EXPENSE):
General and administrative	—			—			64,124			5,388			—			69,512			Interest expense	—			(7,619		)	(46		)	45			(7,620		)
Depreciation and amortization	—			—			77,545			11,929			—			89,474			Other, net	—			1,100			—			(45		)	1,055
Operating Income (Loss)	—			—			(16,697		)	3,912			—			(12,785		)	Income (Loss) Before Income Taxes	—			8,757			(292		)	—			8,465
OTHER INCOME (EXPENSE):																			INCOME TAX PROVISION	—			(601		)	—			—			(601		)
Earnings of unconsolidated entities	—			—			4,875			1,387			—			6,262
Interest expense	(8,313		)	(21,280		)	(18,058		)	(1,517		)	23			(49,145		)	EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	7,876			(280		)	—			(7,596		)	—
Other, net	—			—			(1,056		)	71			(23		)	(1,008		)
																			Net Income (Loss)	7,876			7,876			(292		)	(7,596		)	7,864
Income (Loss) Before Income Taxes	(8,313		)	(21,280		)	(30,936		)	3,853			—			(56,676		)
																			NET INCOME ALLOCATED TO GENERAL PARTNER										(8		)	(8		)
INCOME TAX (PROVISION) BENEFIT	—			—			993			(106		)	—			887
																			NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS										12			12
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(50,886		)	—			337			—			50,549			—
																			NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	7,876		$	7,876		$	(292	)	$	(7,592	)	$	7,868
Net Income (Loss)	(59,199		)	(21,280		)	(29,606		)	3,747			50,549			(55,789		)
																			NGL ENERGY PARTNERS LP
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(20,437		)	(20,437		)	Condensed Consolidating Statements of Comprehensive Income (Loss)
																			(U.S. Dollars in Thousands)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,410		)	(3,410		)
																				Year Ended March 31, 2014
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	26,702		$	(79,636	)		NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
																				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
																			Net income (loss)	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(69,244	)	$	48,758
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Operations																			Other comprehensive loss, net of tax	—			—			(189		)	(71		)	—			(260		)
(U.S. Dollars in Thousands)
																			Comprehensive income (loss)	$	47,655		$	(15,000	)	$	79,284		$	5,803		$	(69,244	)	$	48,498
	Six Months Ended September 30, 2013
	NGL Energy																		(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	Partners LP			Guarantor			Non-Guarantor			Consolidating
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated							Year Ended March 31, 2013
																				NGL Energy
REVENUES	$	—		$	2,914,531		$	65,421		$	(58	)	$	2,979,894						Partners LP			Guarantor			Non-Guarantor			Consolidating
																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
COST OF SALES	—			2,735,890			56,094			(58		)	2,791,926
																			Net income	$	47,940		$	60,981		$	534		$	(61,265	)	$	48,190
OPERATING COSTS AND EXPENSES:
Operating	—			99,710			5,104			—			104,814						Other comprehensive loss, net of tax	—			—			(7		)	—			(7		)
General and administrative	—			32,297			469			—			32,766
Depreciation and amortization	—			46,000			1,785			—			47,785						Comprehensive income	$	47,940		$	60,981		$	527		$	(61,265	)	$	48,183
Operating Income	—			634			1,969			—			2,603							Year Ended March 31, 2012
																				NGL Energy
OTHER INCOME (EXPENSE):																				Partners LP			Guarantor			Non-Guarantor			Consolidating
Interest expense	(8,368		)	(13,309		)	(28		)	23			(21,682		)					(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
Other, net	—			627			(135		)	(23		)	469
																			Net income (loss)	$	7,876		$	7,876		$	(292	)	$	(7,596	)	$	7,864
Income (Loss) Before Income Taxes	(8,368		)	(12,048		)	1,806			—			(18,610		)
																			Other comprehensive loss, net of tax	—			—			(25		)	—			(25		)
INCOME TAX BENEFIT	—			170			—			—			170
																			Comprehensive income (loss)	$	7,876		$	7,876		$	(317	)	$	(7,596	)	$	7,839
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(10,206		)	1,672			—			8,534			—
																			NGL ENERGY PARTNERS LP
Net Income (Loss)	(18,574		)	(10,206		)	1,806			8,534			(18,440		)				Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(4,139		)	(4,139		)
																				Year Ended March 31, 2014
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(134		)	(134		)					NGL Energy
																				Partners LP			NGL Energy			Guarantor			Non-Guarantor
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(18,574	)	$	(10,206	)	$	1,806		$	4,261		$	(22,713	)					(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated
																			OPERATING ACTIVITIES:
NGL ENERGY PARTNERS LP																			Net cash provided by (used in) operating activities	$	(16,625	)	$	—		$	99,754		$	2,107		$	85,236
Condensed Consolidating Statements of Comprehensive Income (Loss)
(U.S. Dollars in Thousands)																			INVESTING ACTIVITIES:
																			Purchases of long-lived assets	—			—			(118,455		)	(46,693		)	(165,148		)
	Three Months Ended September 30, 2014																		Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,154		)	—			(932,373		)	(2,283		)	(1,268,810		)
	NGL Energy																		Cash flows from commodity derivatives	—			—			(35,956		)	—			(35,956		)
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						Proceeds from sales of assets	—			—			12,884			11,776			24,660
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			Investments in unconsolidated entities	—			—			(11,515		)	—			(11,515		)
																			Distributions of capital from unconsolidated entities	—			—			1,591			—			1,591
Net income (loss)	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	14,553		$	(15,879	)	Other	—			—			540			(735		)	(195		)
																			Net cash used in investing activities	(334,154		)	—			(1,083,284		)	(37,935		)	(1,455,373		)
Other comprehensive income (loss)	—			—			4			(26		)	—			(22		)
																			FINANCING ACTIVITIES:
Comprehensive income (loss)	$	(19,224	)	$	(13,134	)	$	(2,019	)	$	3,923		$	14,553		$	(15,901	)	Proceeds from borrowings under revolving credit facilities	—			—			2,545,500			—			2,545,500
																			Payments on revolving credit facilities	—			—			(2,101,000		)	—			(2,101,000		)
																			Issuances of notes	—			450,000			—			—			450,000
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Proceeds from borrowings on other long-term debt	—			—			780			100			880
																			Payments on other long-term debt	—			—			(8,802		)	(17		)	(8,819		)
	Three Months Ended September 30, 2013																		Debt issuance costs	(645		)	(12,286		)	(11,664		)	—			(24,595		)
	NGL Energy																		Contributions	765			—			—			2,060			2,825
	Partners LP			Guarantor			Non-Guarantor			Consolidating									Distributions	(145,090		)	—			—			(840		)	(145,930		)
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Proceeds from sale of common units, net of offering costs	650,155			—			—			—			650,155
																			Net changes in advances with consolidated entities	(153,225		)	(437,714		)	556,238			34,701			—
Net income (loss)	$	(941	)	$	3,238		$	89		$	(3,318	)	$	(932	)				Net cash provided by financing activities	351,960			—			981,052			36,004			1,369,016
																			Net increase (decrease) in cash and cash equivalents	1,181			—			(2,478		)	176			(1,121		)
Other comprehensive loss	—			—			(5		)	—			(5		)				Cash and cash equivalents, beginning of period	—			—			11,206			355			11,561
																			Cash and cash equivalents, end of period	$	1,181		$	—		$	8,728		$	531		$	10,440
Comprehensive income (loss)	$	(941	)	$	3,238		$	84		$	(3,318	)	$	(937	)
																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
NGL ENERGY PARTNERS LP
Condensed Consolidating Statements of Comprehensive Income (Loss)																			NGL ENERGY PARTNERS LP
(U.S. Dollars in Thousands)																			Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2014
	NGL Energy																			Year Ended March 31, 2013
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				Partners LP			Guarantor			Non-Guarantor
																				(Parent)			Subsidiaries			Subsidiaries			Consolidated
Net income (loss)	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	50,549		$	(55,789	)	OPERATING ACTIVITIES:
																			Net cash provided by (used in) operating activities	$	(12,428	)	$	140,794		$	4,268		$	132,634
Other comprehensive income (loss)	—			—			189			(26		)	—			163
																			INVESTING ACTIVITIES:
Comprehensive income (loss)	$	(59,199	)	$	(21,280	)	$	(29,417	)	$	3,721		$	50,549		$	(55,626	)	Purchases of long-lived assets	—			(59,903		)	(12,572		)	(72,475		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(452,087		)	(38,718		)	—			(490,805		)
																			Cash flows from commodity derivatives	—			11,579			—			11,579
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Proceeds from sales of assets	—			5,080			—			5,080
																			Net cash used in investing activities	(452,087		)	(81,962		)	(12,572		)	(546,621		)
	Six Months Ended September 30, 2013
	NGL Energy																		FINANCING ACTIVITIES:
	Partners LP			Guarantor			Non-Guarantor			Consolidating									Proceeds from borrowings under revolving credit facilities	—			1,227,975			—			1,227,975
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated						Payments on revolving credit facilities	—			(964,475		)	—			(964,475		)
																			Issuance of notes	250,000			—			—			250,000
Net income (loss)	$	(18,574	)	$	(10,206	)	$	1,806		$	8,534		$	(18,440	)				Proceeds from borrowings on other long-term debt	—			634			19			653
																			Payments on other long-term debt	—			(4,837		)	—			(4,837		)
Other comprehensive loss	—			—			(30		)	—			(30		)				Debt issuance costs	(777		)	(19,412		)	—			(20,189		)
																			Contributions	510			—			403			913
Comprehensive income (loss)	$	(18,574	)	$	(10,206	)	$	1,776		$	8,534		$	(18,470	)				Distributions	(71,608		)	—			(74		)	(71,682		)
																			Proceeds from sale of common units, net of offering costs	(642		)	—			—			(642		)
NGL ENERGY PARTNERS LP																			Net changes in advances with consolidated entities	286,991			(295,105		)	8,114			—
Condensed Consolidating Statement of Cash Flows																			Net cash provided by (used in) financing activities	464,474			(55,220		)	8,462			417,716
(U.S. Dollars in Thousands)																			Net increase (decrease) in cash and cash equivalents	(41		)	3,612			158			3,729
																			Cash and cash equivalents, beginning of period	41			7,594			197			7,832
	Six Months Ended September 30, 2014																		Cash and cash equivalents, end of period	$	—		$	11,206		$	355		$	11,561
	NGL Energy
	Partners LP			NGL Energy			Guarantor			Non-Guarantor									NGL ENERGY PARTNERS LP
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated						Condensed Consolidating Statement of Cash Flows
OPERATING ACTIVITIES:																			(U.S. Dollars in Thousands)
Net cash provided by (used in) operating activities	$	(8,180	)	$	(15,383	)	$	(56,019	)	$	17,947		$	(61,635	)
																				Year Ended March 31, 2012
INVESTING ACTIVITIES:																				NGL Energy
Purchases of long-lived assets	—			—			(81,710		)	(1,141		)	(82,851		)					Partners LP			Guarantor			Non-Guarantor
Acquisitions of businesses, including acquired working capital, net of cash acquired	—			—			(657,514		)	(1,250		)	(658,764		)					(Parent)			Subsidiaries			Subsidiaries			Consolidated
Cash flows from commodity derivatives	—			—			4,327			—			4,327						OPERATING ACTIVITIES:
Proceeds from sales of assets	—			—			8,741			—			8,741						Net cash provided by (used in) operating activities	$	—		$	90,477		$	(148	)	$	90,329
Investments in unconsolidated entities	—			—			(6,106		)	(20,284		)	(26,390		)
Distributions of capital from unconsolidated entities	—			—			2,774			1,875			4,649						INVESTING ACTIVITIES:
Net cash used in investing activities	—			—			(729,488		)	(20,800		)	(750,288		)				Purchases of long-lived assets	—			(6,667		)	(877		)	(7,544		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(291,097		)	(6,304		)	—			(297,401		)
FINANCING ACTIVITIES:																			Cash flows from commodity derivatives	—			6,464			—			6,464
Proceeds from borrowings under revolving credit facilities	—			—			1,923,500			56,000			1,979,500						Proceeds from sales of assets	—			1,238			—			1,238
Payments on revolving credit facilities	—			—			(1,766,000		)	(38,000		)	(1,804,000		)				Other	—			346			—			346
Issuance of notes	—			400,000			—			—			400,000						Net cash used in investing activities	(291,097		)	(4,923		)	(877		)	(296,897		)
Payments on other long-term debt	—			—			(4,173		)	(2		)	(4,175		)
Debt issuance costs	(269		)	(7,209		)	(1,720		)	—			(9,198		)				FINANCING ACTIVITIES:
Contributions	395			—			—			—			395						Proceeds from borrowings under revolving credit facilities	—			478,900			—			478,900
Distributions to owners	(111,008		)	—			—			—			(111,008		)				Payments on revolving credit facilities	—			(329,900		)	—			(329,900		)
Distributions to noncontrolling interest partners	—			—			—			(8,654		)	(8,654		)				Payments on other long-term debt	—			(1,278		)	—			(1,278		)
Proceeds from sale of common units, net of offering costs	370,446			—			—			—			370,446						Debt issuance costs	—			(2,380		)	—			(2,380		)
Net changes in advances with consolidated entities	(249,724		)	(377,408		)	632,995			(5,863		)	—						Contributions	—			—			440			440
Net cash provided by financing activities	9,840			15,383			784,602			3,481			813,306						Distributions	(19,060		)	—			—			(19,060		)
Net increase (decrease) in cash and cash equivalents	1,660			—			(905		)	628			1,383						Proceeds from sale of common units, net of offering costs	74,759			—			—			74,759
Cash and cash equivalents, beginning of period	1,181			—			8,728			531			10,440						Repurchase of common units	(3,418		)	—			—			(3,418		)
Cash and cash equivalents, end of period	$	2,841		$	—		$	7,823		$	1,159		$	11,823					Net changes in advances with consolidated entities	238,816			(239,476		)	660			—
																			Net cash provided by (used in) financing activities	291,097			(94,134		)	1,100			198,063
																			Net increase (decrease) in cash and cash equivalents	—			(8,580		)	75			(8,505		)
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			Cash and cash equivalents, beginning of period	41			16,174			122			16,337
																			Cash and cash equivalents, end of period	$	41		$	7,594		$	197		$	7,832
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Cash Flows
(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2013
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor
	(Parent)			Subsidiaries			Subsidiaries			Consolidated
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	$	(8,312	)	$	(44,607	)	$	4,175		$	(48,744	)
INVESTING ACTIVITIES:
Purchases of long-lived assets	—			(37,180		)	(30,219		)	(67,399		)
Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,085		)	(56,237		)	(2,283		)	(392,605		)
Cash flows from commodity derivatives	—			(19,074		)	—			(19,074		)
Proceeds from sales of assets	—			2,223			1			2,224
Net cash used in investing activities	(334,085		)	(110,268		)	(32,501		)	(476,854		)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facility	—			1,061,500			—			1,061,500
Payments on revolving credit facility	—			(893,000		)	—			(893,000		)
Proceeds from borrowings on other long-term debt	—			780			100			880
Payments on other long-term debt	—			(4,499		)	(8		)	(4,507		)
Debt issuance costs	(133		)	(2,085		)	—			(2,218		)
Contributions	504			—			1,940			2,444
Distributions to owners	(60,258		)	—			(365		)	(60,623		)
Proceeds from sale of common units, net of offering costs	415,089			—			—			415,089
Net changes in advances with consolidated entities	(11,459		)	(15,123		)	26,582			—
Net cash provided by financing activities	343,743			147,573			28,249			519,565
Net increase (decrease) in cash and cash equivalents	1,346			(7,302		)	(77		)	(6,033		)
Cash and cash equivalents, beginning of period	—			11,206			355			11,561
Cash and cash equivalents, end of period	$	1,346		$	3,904		$	278		$	5,528

Subsequent_Events

Subsequent Events	6 Months Ended
	Sep. 30, 2014
Subsequent Events
Subsequent Events	Note 15 — Subsequent Events
	Water Solutions Facility Acquisitions
	As described in Note 4, we are party to a development agreement that provides us a right to purchase water disposal facilities developed by the other party to the agreement. During October and November 2014, we purchased five facilities under this development agreement and paid $52.2 million of cash for these facilities.
	Sale of Natural Gas Liquids Terminal
	In November 2014, we reached an agreement to sell one of our natural gas liquids terminals. We expect the sale to close in December 2014. We expect to record during the three months ending December 31, 2014 a loss on disposal of approximately $29.0 million, consisting of a loss of $21.0 million on property, plant and equipment and $8.0 million of allocated goodwill.

Significant_Accounting_Policie9

Significant Accounting Policies (Policies)	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Significant Accounting Policies
Basis of Presentation	Basis of Presentation					Basis of Presentation
	The unaudited condensed consolidated financial statements as of and for the three months and six months ended September 30, 2014 and 2013 include our accounts and those of our controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All significant intercompany transactions and account balances have been eliminated in consolidation. The unaudited condensed consolidated balance sheet at March 31, 2014 is derived from audited financial statements. We have made certain reclassifications to prior period financial statements to conform to classification methods used in fiscal year 2015. These reclassifications had no impact on previously reported amounts of equity or net income.					Our consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of the Partnership and its controlled subsidiaries. All significant intercompany transactions and account balances have been eliminated in consolidation.
	The accompanying unaudited condensed consolidated financial statements have been 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. 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 of only normal recurring items, unless otherwise disclosed herein. Accordingly, the unaudited condensed consolidated financial statements do not include all the 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 not misleading. These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements for the fiscal year ended March 31, 2014 included in our Annual Report on Form 10-K (the “Annual Report”). Due to the seasonal nature of our natural gas liquids operations and other factors, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.					We have made certain reclassifications to the prior period financial statements to conform with classification methods used in fiscal 2014. These reclassifications had no impact on previously-reported amounts of equity or net income. In addition, certain balances at March 31, 2013 were adjusted to reflect the final acquisition accounting for certain business combinations.
Use of Estimates	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 reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period. Actual results could differ from those estimates.					The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amount of revenues and expenses during the period.
						Critical estimates we make in the preparation of our consolidated financial statements include determining the fair value of assets and liabilities acquired in business combinations; the collectability of accounts receivable; the recoverability of inventories; useful lives and recoverability of property, plant and equipment and amortizable intangible assets; the impairment of goodwill; the fair value of derivative financial investments; and accruals for various commitments and contingencies, among others. Although we believe these estimates are reasonable, actual results could differ from those estimates.
Revenue Recognition	Revenue Recognition					Revenue Recognition
	We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, transportation, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Pursuant to terminaling services agreements with certain of our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Such measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Revenues for our water solutions business are recognized upon receipt of the wastewater at our disposal facilities.					We record revenues from product sales at the time title to the product transfers to the purchaser, which typically occurs upon receipt of the product by the purchaser. We record terminaling, storage, and service revenues at the time the service is performed, and we record tank and other rentals over the term of the lease. Revenues for the wastewater disposal business are recognized upon receipt of the wastewater at our disposal facilities.
	We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in our condensed consolidated statements of operations.					We report taxes collected from customers and remitted to taxing authorities, such as sales and use taxes, on a net basis. Amounts billed to customers for shipping and handling costs are included in revenues in the 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 concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.					We enter into certain contracts whereby we agree to purchase product from a counterparty and to sell the same volume of product to the same counterparty at a different location or time. When such agreements are entered into concurrently and are entered into in contemplation of each other, we record the revenues for these transactions net of cost of sales.
Fair Value Measurements	Fair Value Measurements					Fair Value Measurements
	We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.					We apply fair value measurements to certain assets and liabilities, principally our commodity derivative instruments and assets and liabilities acquired in business combinations. 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, including assumptions about risk and risks inherent in valuation techniques and inputs to valuations. This includes not only the credit standing of counterparties and credit enhancements but also the impact of our own nonperformance risk on our liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability or, in the absence of a principal market, the most advantageous market for the asset or liability (the market for which the reporting entity would be able to maximize the amount received or minimize the amount paid). We evaluate the need for credit adjustments to our derivative instrument fair values in accordance with the requirements noted above. Such adjustments were not material to the fair values of our derivative instruments.
	We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:					We use the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	·         Level 1 — Quoted prices (unadjusted) in active markets for identical assets and liabilities that we have the ability to access at the measurement date.					·                  Level 1 — Quoted prices (unadjusted) 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 quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at September 30, 2014 and March 31, 2014 (see Note 11). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model include publicly available prices and forward curves generated from a compilation of data gathered from third parties.					·                  Level 2 — Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter commodity price swap and option contracts and interest rate protection agreements. The majority of our fair value measurements related to our derivative financial instruments were categorized as Level 2 at March 31, 2014 and 2013 (see Note 12). We determine the fair value of all our derivative financial instruments utilizing pricing models for significantly similar instruments. Inputs to the pricing model 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. We did not have any fair value measurements categorized as Level 3 at September 30, 2014 or March 31, 2014.					·                  Level 3 — Unobservable inputs for the asset or liability including situations where there is little, if any, market activity for the asset or liability. We did not have any fair value measurements categorized as Level 3 at March 31, 2014 or 2013.
	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 the fair value measurement requires judgment, considering factors specific to 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 the fair value measurement requires judgment, considering factors specific to the asset or liability.
Supplemental Cash Flow Information	Supplemental Cash Flow Information
	Cash flows from settlements of commodity derivative instruments are classified as cash flows from investing activities in the condensed consolidated statements of cash flows, and adjustments to the fair value of commodity derivative instruments are included in the reconciliation of net loss to net cash used in operating activities.
Inventories	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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.					We value our inventory 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. In performing this analysis, we take into consideration fixed-price forward sale commitments and the opportunity to transfer propane inventory from our wholesale business to our retail business for sale in the retail markets.
						Inventories consist of the following:
							March 31,
							2014		2013
							(in thousands)
						Crude oil	$	156,473	$	46,156
						Natural gas liquids —
						Propane	85,159		45,428
						Butane and other	19,051		24,090
						Refined products	23,209		—
						Renewables	11,778		—
						Other	14,490		11,221
							$	310,160	$	126,895
Investments in Unconsolidated Entities	Investments in Unconsolidated Entities					Investments in Unconsolidated Entities
	In December 2013, as part of our acquisition of Gavilon, LLC (“Gavilon Energy”), we acquired a 50% interest in Glass Mountain Pipeline, LLC (“Glass Mountain”) and an 11% interest in a limited liability company that owns an ethanol production facility. In June 2014, we acquired an interest in a limited liability company that operates a water supply business. On July 1, 2014, as part of our acquisition of TransMontaigne Inc. (“TransMontaigne”), we acquired TLP, which owns a 42.5% interest in BOSTCO and a 50% interest in Frontera. We account for these investments 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 book value of the net assets of the investment entity.					As part of the December 2013 acquisition of Gavilon Energy, we acquired a 50% interest in Glass Mountain and an 11% interest in a limited liability company that owns an ethanol production facility. We account for these investments under the equity method of accounting. Under the equity method, we do not report the individual assets and liabilities of these entities on our consolidated balance sheet; instead, our ownership interests are reported within “Investments in Unconsolidated Entities” on our consolidated balance sheet. We record our share of any income or loss generated by these entities as an increase to our equity method investments, and record any distributions we receive from these entities as reductions to our equity method investments.
	Our investments in unconsolidated entities consist of the following:
		September 30,		March 31,
		2014		2014
		(in thousands)
	Glass Mountain (1)	$	189,847	$	181,488
	Ethanol production facility	9,361		8,333
	Water supply company	15,026		—
	BOSTCO (2)	244,092		—
	Frontera	24,318		—
	Total	$	482,644	$	189,821
	(1)     When we acquired Gavilon we recorded the investment in Glass Mountain at fair value. The fair value of our investment in Glass Mountain exceeds our share of the historical net book value of Glass Mountain’s net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.
	(2)     When we acquired TransMontaigne, we recorded the investment in BOSTCO at fair value. The fair value of our investment in BOSTCO exceeds our share of the historical net book value of BOSTCO’s net assets by approximately $24 million.
Business Combination Measurement Period	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 fair value of the assets acquired and liabilities assumed in a business combination. As described 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 described in Note 4, we made certain adjustments during the six months ended September 30, 2014 to our estimates of the acquisition-date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2014.					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 to obtain the information necessary to identify and measure the value of the assets acquired and liabilities assumed in a business combination. As described in Note 4, certain of our acquisitions during the year ended March 31, 2014 are still within this measurement period, and as a result, the acquisition-date fair values we have recorded for the acquired assets and assumed liabilities are subject to change.
						Also as described in Note 4, we made certain adjustments during the year ended March 31, 2014 to our estimates of the acquisition date fair values of assets acquired and liabilities assumed in business combinations that occurred during the year ended March 31, 2013. We retrospectively adjusted the March 31, 2013 consolidated balance sheet for these adjustments. Due to the immateriality of these adjustments, we did not retrospectively adjust the consolidated statement of operations for the year ended March 31, 2013 for these measurement period adjustments.
Noncontrolling Interests	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’ share of these entities.					We have certain consolidated subsidiaries in which outside parties own interests. The noncontrolling interest shown in our consolidated statements of operations represents the other owners’ share of the net income (loss) of these entities.
	On July 1, 2014, as part of our acquisition of TransMontaigne, we acquired a 19.7% limited partner interest in TLP. We have attributed net earnings allocable to TLP’s limited partners to the controlling and noncontrolling interests based on the relative ownership interests in TLP as well as including certain adjustments related to our acquisition accounting. Net earnings allocable to TLP’s limited partners are net of the earnings allocable to TLP’s general partner interest. The earnings allocable to TLP’s general partner interest include the distributions of available cash (as defined by TLP’s partnership agreement) attributable to the period to TLP’s general partner interest and incentive distribution rights, net of adjustments for TLP’s general partner’s share of undistributed earnings. Undistributed earnings are allocated to TLP’s limited partners and TLP’s general partner interest based on their respective sharing of earnings or losses specified in TLP’s partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively.

Recovered_Sheet2

Significant Accounting Policies (Tables)	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Significant Accounting Policies
Schedule of supplemental cash flow information
		Three Months Ended				Six Months Ended
		September 30,				September 30,					Year Ended March 31,
		2014		2013		2014		2013			2014		2013		2012
		(in thousands)									(in thousands)
	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	10,445	$	8,423	$	36,429	$	16,908	Interest paid, exclusive of debt issuance costs and letter of credit fees	$	31,827	$	27,384	$	4,966
	Income taxes paid	$	1,241	$	369	$	2,246	$	650	Income taxes paid	$	1,639	$	1,027	$	430
	Value of common units issued in business combinations	$	—	$	80,619	$	—	$	80,619
Schedule of inventories
											March 31,
		September 30,		March 31,							2014		2013
		2014		2014							(in thousands)
		(in thousands)								Crude oil	$	156,473	$	46,156
	Crude oil	$	136,722	$	156,473					Natural gas liquids —
	Natural gas liquids —									Propane	85,159		45,428
	Propane	207,694		85,159						Butane and other	19,051		24,090
	Butane	84,822		15,106						Refined products	23,209		—
	Other	27,091		3,945						Renewables	11,778		—
	Refined products —									Other	14,490		11,221
	Gasoline	219,111		15,597							$	310,160	$	126,895
	Diesel	214,567		7,298
	Other	3,675		314
	Renewables	36,517		11,778
	Other	11,390		14,490
	Total	$	941,589	$	310,160
Schedule of investments in unconsolidated entities
		September 30,		March 31,
		2014		2014
		(in thousands)
	Glass Mountain (1)	$	189,847	$	181,488
	Ethanol production facility	9,361		8,333
	Water supply company	15,026		—
	BOSTCO (2)	244,092		—
	Frontera	24,318		—
	Total	$	482,644	$	189,821
	(1)     When we acquired Gavilon we recorded the investment in Glass Mountain at fair value. The fair value of our investment in Glass Mountain exceeds our share of the historical net book value of Glass Mountain’s net assets by approximately $70 million. This difference relates primarily to goodwill and customer relationships.
	(2)     When we acquired TransMontaigne, we recorded the investment in BOSTCO at fair value. The fair value of our investment in BOSTCO exceeds our share of the historical net book value of BOSTCO’s net assets by approximately $24 million.
Schedule of accrued expenses and other payables
		September 30,		March 31,							March 31,
		2014		2014									2013
		(in thousands)									2014		(Note 4)
	Accrued compensation and benefits	$	49,146	$	45,006						(in thousands)
	Derivative liabilities	39,023		42,214						Accrued compensation and benefits	$	45,006	$	27,252
	Product exchange liabilities	43,185		3,719						Derivative liabilities	42,214		12,701
	Accrued interest	23,945		18,668						Income and other tax liabilities	13,421		22,659
	Income and other tax liabilities	38,255		13,421						Product exchange liabilities	3,719		6,741
	Other	24,928		18,662						Other	37,330		16,253
	Total	$	218,482	$	141,690						$	141,690	$	85,606

Recovered_Sheet3

Earnings Per Unit (Tables)	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Earnings Per Unit
Schedule of earnings per common unit
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands, except unit and per unit amounts)
		(in thousands, except unit and per unit amounts)
	Net loss attributable to parent equity	$	(19,224	)	$	(941	)	$	(59,199	)	$	(18,574	)	Income attributable to parent equity	$	47,655		$	47,940		$	7,876
	Less: net income allocated to general partner (1)	(11,056		)	(2,451		)	(20,437		)	(4,139		)	Income allocated to general partner (1)	(14,148		)	(2,917		)	(8		)
	Net loss allocated to subordinated unitholders (2)	—			562			4,013			3,076			Income attributable to limited partners	$	33,507		$	45,023		$	7,868
	Net loss allocated to common unitholders	$	(30,280	)	$	(2,830	)	$	(75,623	)	$	(19,637	)
														Income allocated to:
	Weighted average common units outstanding	88,331,653			58,909,389			81,267,742			53,336,969			Common unitholders	$	31,614		$	39,517		$	4,859
														Subordinated unitholders	$	1,893		$	5,506		$	3,009
	Loss per common unit - basic and diluted	$	(0.34	)	$	(0.05	)	$	(0.93	)	$	(0.37	)
														Weighted average common units outstanding	61,970,471			41,353,574			15,169,983
														Weighted average subordinated units outstanding	5,919,346			5,919,346			5,175,384
	(1)     The net income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights, which are described in Note 10.
	(2)     All outstanding subordinated units converted to common units in August 2014. Since the subordinated units did not share in the distribution of cash generated during the three months ended September 30, 2014, we did not allocate any earnings or loss during this period to the subordinated unitholders. During the three months ended June 30, 2014 and the six months ended September 30, 2013, 5,919,346 subordinated units were outstanding. The loss per subordinated unit was $(0.68) for the three months ended June 30, 2014, $(0.09) for the three months ended September 30, 2013, and $(0.52) for the six months ended September 30, 2013.													Income per common unit - basic and diluted	$	0.51		$	0.96		$	0.32
														Income per subordinated unit - basic and diluted	$	0.32		$	0.93		$	0.58
														(1)         The income allocated to the general partner includes distributions to which it is entitled as the holder of incentive distribution rights (“IDRs”), which are described in Note 11.

Acquisitions_Tables1

Acquisitions (Tables)	6 Months Ended										12 Months Ended
	Sep. 30, 2014										Mar. 31, 2014
Acquisitions
Schedule of future amortization of liability	The future amortization of this liability is shown below (in thousands):										The future amortization of this liability is shown below (in thousands):
	Year Ending March 31,										Year Ending March 31,
	2015 (six months)	$	3,670								2015	$	6,500
	2016	4,040									2016	3,260
	2017	360									2017	300
TransMontaigne Inc
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed	We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	Cash and cash equivalents	$	1,469
	Accounts receivable - trade	197,349
	Accounts receivable - affiliates	528
	Inventories	426,913
	Prepaid expenses and other current assets	15,373
	Property, plant and equipment:
	Refined products terminal assets (20 years)	418,405
	Buildings and leasehold improvements (20 years)	10,339
	Crude oil tanks and related equipment (20 years)	28,666
	Vehicles	1,565
	Land	56,095
	Information technology equipment	7,851
	Other	12,592
	Construction in progress	4,487
	Goodwill (1)	29,118
	Intangible assets:
	Customer relationships (7 years)	50,000
	Pipeline capacity rights (30 years)	87,000
	Trade names (indefinite life)	5,000
	Equity method investments	250,000
	Other noncurrent assets	3,911
	Accounts payable - trade	(140,597		)
	Accounts payable - affiliates	(69		)
	Accrued expenses and other payables	(73,565		)
	Advance payments received from customers	(1,919		)
	Long-term debt	(234,000		)
	Other noncurrent liabilities	(34,856		)
	Noncontrolling interests	(567,120		)
	Fair value of net assets acquired	$	554,535
	(1)     Included in the refined products and renewables segment.
Water Solutions Facilities
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed	We have preliminarily estimated the fair values of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
	Accounts receivable - trade	$	939
	Inventories	253
	Prepaid expenses and other current assets	62
	Property, plant and equipment:
	Water treatment facilities and equipment (5–40 years)	23,066
	Buildings and leasehold improvements (3–7 years)	2,599
	Land	1,010
	Other (7 years)	33
	Goodwill	57,777
	Other noncurrent assets	50
	Accounts payable - trade	(58		)
	Accrued expenses and other payables	(1,092		)
	Other noncurrent liabilities	(149		)
	Noncontrolling interest	(1,620		)
	Fair value of net assets acquired	$	82,870
Gavilon Energy
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated at						Accounts receivable - trade	$	349,529
					at						Accounts receivable - affiliates	2,564
					March 31,						Inventories	107,430
		Final			2014			Change			Prepaid expenses and other current assets	68,322
		(in thousands)									Property, plant and equipment:
	Accounts receivable - trade	$	326,484		$	349,529		$	(23,045	)	Crude oil tanks and related equipment (3—40 years)	77,429
	Accounts receivable - affiliates	2,564			2,564			—			Vehicles (3 years)	791
	Inventories	107,430			107,430			—			Information technology equipment (3—7 years)	4,046
	Prepaid expenses and other current assets	68,322			68,322			—			Buildings and leasehold improvements (3—40 years)	7,716
	Property, plant and equipment:										Land	6,427
	Vehicles (3 years)	327			791			(464		)	Linefill and tank bottoms	15,230
	Crude oil tanks and related equipment (3–40 years)	83,797			77,429			6,368			Other (7 years)	170
	Information technology equipment (3–7 years)	4,049			4,046			3			Construction in process	7,190
	Buildings and leasehold improvements (3–40 years)	7,817			7,716			101			Goodwill	359,169
	Land	6,427			6,427			—			Intangible assets:
	Tank bottoms	16,930			15,230			1,700			Customer relationships (10—20 years)	101,600
	Other (7 years)	162			170			(8		)	Lease agreements (1—5 years)	8,700
	Construction in progress	7,180			7,190			(10		)	Investments in unconsolidated entities	178,000
	Goodwill (1)	342,769			359,169			(16,400		)	Other noncurrent assets	9,918
	Intangible assets:										Accounts payable - trade	(342,792		)
	Customer relationships (10–20 years)	107,950			101,600			6,350			Accounts payable - affiliates	(2,585		)
	Lease agreements (1–5 years)	8,700			8,700			—			Accrued expenses and other payables	(70,999		)
	Pipeline capacity rights (30 years)	7,800			—			7,800			Advance payments received from customers	(10,667		)
	Investments in unconsolidated entities	183,000			178,000			5,000			Other noncurrent liabilities	(44,740		)
	Other noncurrent assets	2,287			9,918			(7,631		)	Fair value of net assets acquired	$	832,448
	Accounts payable - trade	(342,792		)	(342,792		)	—
	Accounts payable - affiliates	(2,585		)	(2,585		)	—
	Accrued expenses and other payables	(49,447		)	(70,999		)	21,552
	Advance payments received from customers	(10,667		)	(10,667		)	—
	Other noncurrent liabilities	(46,056		)	(44,740		)	(1,316		)
	Fair value of net assets acquired	$	832,448		$	832,448		$	—
	(1)     Primarily included in the crude oil logistics segment.
Oilfield Water Lines LP
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated						Accounts receivable - trade	$	7,268
					at						Inventories	154
					March 31,						Prepaid expenses and other current assets	402
		Final			2014			Change			Property, plant and equipment:
		(in thousands)									Land	710
	Accounts receivable - trade	$	6,837		$	7,268		$	(431	)	Water treatment facilities and equipment (3—30 years)	23,173
	Inventories	154			154			—			Vehicles (5—10 years)	8,157
	Prepaid expenses and other current assets	402			402			—			Buildings and leasehold improvements (7—30 years)	2,198
	Property, plant and equipment:										Other (3—5 years)	53
	Vehicles (5–10 years)	8,143			8,157			(14		)	Intangible assets:
	Water treatment facilities and equipment (3–30 years)	23,173			23,173			—			Customer relationships (10 years)	110,000
	Buildings and leasehold improvements (7–30 years)	2,198			2,198			—			Non-compete agreements (2.5 years)	2,000
	Land	710			710			—			Goodwill	89,699
	Other (3–5 years)	53			53			—			Accounts payable - trade	(6,469		)
	Intangible assets:										Accrued expenses and other payables	(992		)
	Customer relationships (8–10 years)	110,000			110,000			—			Other noncurrent liabilities	(64		)
	Non-compete agreements (3 years)	2,000			2,000			—			Fair value of net assets acquired	$	236,289
	Goodwill	90,144			89,699			445
	Accounts payable - trade	(6,469		)	(6,469		)	—
	Accrued expenses and other payables	(992		)	(992		)	—
	Other noncurrent liabilities	(64		)	(64		)	—
	Fair value of net assets acquired	$	236,289		$	236,289		$	—
Other Water Solutions
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed
					Estimated
					at
					March 31,
		Final			2014			Change
		(in thousands)
	Accounts receivable - trade	$	2,146		$	2,146		$	—
	Inventories	192			192			—
	Prepaid expenses and other current assets	62			61			1
	Property, plant and equipment:
	Vehicles (5–10 years)	76			90			(14		)
	Water treatment facilities and equipment (3–30 years)	11,717			14,394			(2,677		)
	Buildings and leasehold improvements (7–30 years)	3,278			1,906			1,372
	Land	207			206			1
	Other (3–5 years)	12			12			—
	Intangible assets:
	Customer relationships (8–10 years)	72,000			72,000			—
	Trade names (indefinite life)	3,325			3,325			—
	Non-compete agreements (3 years)	260			260			—
	Water facility development agreement (5 years)	14,000			14,000			—
	Water facility option agreement	2,500			2,500			—
	Goodwill	49,067			47,750			1,317
	Accounts payable - trade	(119		)	(119		)	—
	Accrued expenses and other payables	(293		)	(293		)	—
	Other noncurrent liabilities	(64		)	(64		)	—
	Fair value of net assets acquired	$	158,366		$	158,366		$	—
Disposal facilities acquired under option and development agreements
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed
		Estimated At
		September 30,			March 31,
		2014			2014			Change
		(in thousands)
	Accounts receivable - trade	$	124		$	245		$	(121	)
	Inventories	119			197			(78		)
	Property, plant and equipment:
	Water treatment facilities and equipment (3–30 years)	10,539			10,540			(1		)
	Buildings and leasehold improvements (7–30 years)	1,130			1,130			—
	Land	213			213			—
	Other (3–5 years)	1			1			—
	Goodwill	15,443			15,281			162
	Accounts payable - trade	(232		)	(263		)	31
	Accrued expenses and other payables	—			(7		)	7
	Other noncurrent liabilities	(50		)	(50		)	—
	Fair value of net assets acquired	$	27,287		$	27,287		$	—
Crude Oil Logistics
Acquisitions
Schedule of the fair values (and useful lives) of the assets acquired and liabilities assumed											We have preliminarily estimated the fair value of the assets acquired (and useful lives) and liabilities assumed as follows (in thousands):
					Estimated						Accounts receivable - trade	$	1,235
					at						Inventories	1,021
					March 31,						Prepaid expenses and other current assets	54
		Final			2014			Change			Property, plant and equipment:
		(in thousands)									Vehicles (5—10 years)	2,977
	Accounts receivable - trade	$	1,221		$	1,235		$	(14	)	Buildings and leasehold improvements (5—30 years)	280
	Inventories	1,021			1,021			—			Crude oil tanks and related equipment (2—30 years)	3,462
	Prepaid expenses and other current assets	58			54			4			Barges and towboats (20 years)	20,065
	Property, plant and equipment:										Other (3—5 years)	53
	Vehicles (5–10 years)	2,980			2,977			3			Intangible assets:
	Buildings and leasehold improvements (5–30 years)	58			280			(222		)	Customer relationships (3 years)	6,300
	Crude oil tanks and related equipment (2–30 years)	3,822			3,462			360			Non-compete agreements (3 years)	35
	Barges and towboats (20 years)	20,065			20,065			—			Trade names (indefinite life)	530
	Other (3–5 years)	57			53			4			Goodwill	37,867
	Intangible assets:										Accounts payable - trade	(665		)
	Customer relationships (3 years)	13,300			6,300			7,000			Accrued expenses and other payables	(124		)
	Non-compete agreements (3 years)	35			35			—			Fair value of net assets acquired	$	73,090
	Trade names (indefinite life)	530			530			—
	Goodwill	30,730			37,867			(7,137		)
	Accounts payable - trade	(521		)	(665		)	144
	Accrued expenses and other payables	(266		)	(124		)	(142		)
	Fair value of net assets acquired	$	73,090		$	73,090		$	—

Property_Plant_and_Equipment_T1

Property, Plant and Equipment (Tables)	6 Months Ended						12 Months Ended
	Sep. 30, 2014						Mar. 31, 2014
Property, Plant and Equipment
Schedule of property, plant and equipment
		September 30,		March 31,				March 31,
	Description and Estimated Useful Lives	2014		2014							2013
		(in thousands)					Description and Estimated Useful Lives	2014			(Note 2)
	Natural gas liquids terminal assets (2–30 years)	$	127,258	$	75,141			(in thousands)
	Refined products and renewables terminal assets and equipment (20 years)	419,411		—			Natural gas liquids terminal assets (2—30 years)	$	75,141		$	63,637
	Retail propane equipment (2–30 years)	167,825		160,758			Retail propane equipment (2—30 years)	160,758			152,802
	Vehicles and railcars (3–25 years)	172,799		152,676			Vehicles (3—25 years)	152,676			88,173
	Water treatment facilities and equipment (3–30 years)	209,644		180,985			Water treatment facilities and equipment (3—30 years)	180,985			91,944
	Crude oil tanks and related equipment (2–40 years)	145,287		106,125			Crude oil tanks and related equipment (2—40 years)	106,125			22,577
	Barges and towboats (5–40 years)	56,094		52,217			Barges and towboats (5—40 years)	52,217			25,963
	Information technology equipment (3–7 years)	30,519		20,768			Information technology equipment (3—7 years)	20,768			12,169
	Buildings and leasehold improvements (3–40 years)	77,415		60,004			Buildings and leasehold improvements (3—40 years)	60,004			48,975
	Land	88,350		30,241			Land	30,241			21,815
	Tank bottoms	17,679		13,403			Linefill and tank bottoms	13,403			—
	Other (3–30 years)	16,770		6,341			Other (5—30 years)	6,341			16,104
	Construction in progress	57,319		80,251			Construction in progress	80,251			32,405
		1,586,370		938,910				938,910			576,564
	Less: Accumulated depreciation	-153,057		(109,564		)	Less: Accumulated depreciation	(109,564		)	(50,127		)
	Net property, plant and equipment	$	1,433,313	$	829,346		Net property, plant and equipment	$	829,346		$	526,437

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Tables)	6 Months Ended														12 Months Ended
	Sep. 30, 2014														Mar. 31, 2014
Goodwill and Intangible Assets
Schedule of changes in the balance of goodwill	The changes in the balance of goodwill during the six months ended September 30, 2014 were as follows (in thousands):
	Beginning of period	$	1,107,006													Year Ended March 31,
	Revisions to acquisition accounting (Note 4)	(21,614		)												2014			2013			2012
	Acquisitions (Note 4)	86,895														(in thousands)
	Disposal	(1,797		)											Beginning of period, as retrospectively adjusted (Note 2)	$	555,220		$	167,245		$	8,568
	End of period	$	1,170,490												Acquisitions	551,786			387,975			158,677
															End of period, as retrospectively adjusted (Note 2)	$	1,107,006		$	555,220		$	167,245
Schedule of goodwill by reportable segment, including changes to goodwill
		September 30,			March 31,											March 31,
		2014			2014											2014			2013
		(in thousands)														(in thousands)
	Crude oil logistics	$	579,845		$	606,383									Crude oil logistics	$	606,383		$	246,345
	Water solutions	320,106			262,203										Water solutions	262,203			109,470
	Liquids	91,135			90,135										Liquids	90,135			87,136
	Retail propane	114,285			114,285										Retail propane	114,285			112,269
	Refined products and renewables	65,119			34,000										Refined products	22,000			—
	Total	$	1,170,490		$	1,107,006									Renewables	12,000			—
																$	1,107,006		$	555,220
Schedule of intangible assets
				September 30, 2014						March 31, 2014								March 31, 2014						March 31, 2013
		Amortizable		Gross Carrying			Accumulated			Gross Carrying			Accumulated											Gross Carrying
		Lives		Amount			Amortization			Amount			Amortization			Amortizable		Gross Carrying			Accumulated			Amount		Accumulated
				(in thousands)												Lives		Amount			Amortization			(Note 2)		Amortization
	Amortizable —																				(in thousands)
	Customer relationships (1)	3–20 years		$	761,992		$	119,439		$	697,405		$	83,261	Amortizable -
	Pipeline capacity rights	30 years		94,800			942			—			—		Customer relationships (1)	3–20 years		$	697,405		$	83,261		$	405,160	$	30,959
	Water facility development agreement	5 years		14,000			3,500			14,000			2,100		Water facility development agreement	5 years		14,000			2,100			—		—
	Executory contracts and other agreements	5–10 years		23,920			16,367			23,920			13,190		Lease and other agreements	5–8 years		23,920			13,190			15,210		7,018
	Non-compete agreements	2–7 years		14,412			8,302			14,161			6,388		Non-compete agreements	2–7 years		14,161			6,388			11,509		2,871
	Trade names	2–10 years		14,539			5,197			15,489			3,081		Trade names	1–10 years		15,489			3,081			2,784		326
	Debt issuance costs	5–10 years		53,289			12,737			44,089			8,708		Debt issuance costs	5–10 years		44,089			8,708			19,494		2,981
	Total amortizable			976,952			166,484			809,064			116,728		Total amortizable			809,064			116,728			454,157		44,155
	Non-amortizable —														Non-amortizable -
	Trade names			27,620						22,620					Trade names			22,620						31,430
	Total			$	1,004,572		$	166,484		$	831,684		$	116,728	Total			$	831,684		$	116,728		$	485,587	$	44,155
	(1)     The weighted-average remaining amortization period for customer relationship intangible assets is approximately 9 years.														(1)         The weighted-average remaining amortization period for customer relationship intangible assets is approximately nine years.
Schedule of amortization expense
		Three Months Ended						Six Months Ended								Year Ended March 31,
		September 30,						September 30,							Recorded in	2014			2013			2012
	Recorded In	2014			2013			2014			2013					(in thousands)
		(in thousands)													Depreciation and amortization	$	60,855		$	29,657		$	4,538
	Depreciation and amortization	$	21,711		$	11,324		$	42,604		$	20,600			Cost of sales	6,172			5,285			800
	Cost of sales	1,984			949			4,121			1,574				Interest expense	5,727			3,375			1,277
	Interest expense	2,117			1,065			4,029			2,462				Loss on early extinguishment of debt	—			5,769			—
	Total	$	25,812		$	13,338		$	50,754		$	24,636				$	72,754		$	44,086		$	6,615
Schedule of expected amortization of intangible assets	Expected amortization of our intangible assets is as follows (in thousands):														Expected amortization of our intangible assets is as follows (in thousands):
	Year Ending March 31,														Year Ending March 31,
	2015 (six months)	$	50,570												2015	$	88,970
	2016	97,432													2016	83,449
	2017	90,795													2017	76,826
	2018	86,818													2018	72,857
	2019	79,587													2019	66,826
	Thereafter	405,266													Thereafter	303,408
	Total	$	810,468													$	692,336

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended																12 Months Ended
	Sep. 30, 2014																Mar. 31, 2014
Long-Term Debt
Schedule of long-term debt
		September 30,			March 31,													March 31,
		2014			2014													2014		2013
		(in thousands)																(in thousands)
	Revolving credit facility —																Revolving credit facility —
	Expansion capital borrowings	$	137,000		$	532,500											Expansion capital loans	$	532,500	$	441,500
	Working capital borrowings	942,500			389,500												Working capital loans	389,500		36,000
	5.125% Notes due 2019	400,000			—												Senior notes	250,000		250,000
	6.875% Notes due 2021	450,000			450,000												Unsecured notes	450,000		—
	6.650% Notes due 2022	250,000			250,000												Other notes payable	14,914		21,562
	TLP credit facility	252,000			—													1,636,914		749,062
	Other long-term debt	10,913			14,914
		2,442,413			1,636,914												Less - current maturities	7,080		8,626
	Less - current maturities	5,062			7,080												Long-term debt	$	1,629,834	$	740,436
	Long-term debt	$	2,437,351		$	1,629,834
Schedule of outstanding borrowings and interest rates under Revolving Credit Facility	At September 30, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):																At March 31, 2014, our outstanding borrowings and interest rates under our Revolving Credit Facility were as follows (dollars in thousands):
		Amount			Rate													Amount		Rate
	Expansion Capital Facility —																Expansion capital facility —
	LIBOR borrowings	$	137,000		1.91	%											LIBOR borrowings	$	532,500	1.91	%
	Working Capital Facility —																Working capital facility —
	LIBOR borrowings	942,500			1.91	%											LIBOR borrowings	358,000		1.91	%
																	Base rate borrowings	31,500		4	%
Schedule of maturities of long-term debt
		Revolving									TLP		Other					Revolving						Other
		Credit			2019		2021		2022		Credit		Long-Term					Credit		Senior		Unsecured		Notes
	Year Ending March 31,	Facility			Notes		Notes		Notes		Facility		Debt		Total		Year Ending March 31,	Facility		Notes		Notes		Payable		Total
		(in thousands)																				(in thousands)
	2015 (six months)	$	—		$	—	$	—	$	—	$	—	$	2,345	$	2,345	2015	$	—	$	—	$	—	$	7,081	$	7,081
	2016	—			—		—		—		252,000		3,128		255,128		2016	—		—		—		3,614		3,614
	2017	—			—		—		—		—		2,362		2,362		2017	—		—		—		2,356		2,356
	2018	—			—		—		25,000		—		1,459		26,459		2018	—		25,000		—		1,449		26,449
	2019	1,079,500			—		—		50,000		—		1,438		1,130,938		2019	922,000		50,000		—		238		972,238
	Thereafter	—			400,000		450,000		175,000		—		181		1,025,181		Thereafter	—		175,000		450,000		176		625,176
	Total	$	1,079,500		$	400,000	$	450,000	$	250,000	$	252,000	$	10,913	$	2,442,413		$	922,000	$	250,000	$	450,000	$	14,914	$	1,636,914
TLP
Long-Term Debt
Summary of assets and liabilities	The following table summarizes our basis in the assets and liabilities of TLP at September 30, 2014, inclusive of the impact of our acquisition accounting for the business combination with TransMontaigne (in thousands):
	Cash and cash equivalents	$	726
	Accounts receivable - trade, net	12,252
	Accounts receivable - affiliates	1,105
	Inventories	1,613
	Prepaid expenses and other current assets	1,363
	Property, plant and equipment, net	504,272
	Goodwill	29,118
	Intangible assets, net	38,571
	Investments in unconsolidated entities	268,410
	Other noncurrent assets	1,910
	Accounts payable - trade	(4,009		)
	Accounts payable - affiliates	(146		)
	Accrued expenses and other payables	(11,625		)
	Advanced payments received from customers	(141		)
	Long-term debt	(252,000		)
	Other noncurrent liabilities	(4,247		)
	Net assets	$	587,172

Commitments_and_Contingencies_3

Commitments and Contingencies (Tables)	6 Months Ended					12 Months Ended
	Sep. 30, 2014					Mar. 31, 2014
Commitments and Contingencies
Schedule of future minimum lease payments	Future minimum lease payments under these agreements at September 30, 2014 are as follows (in thousands):					Future minimum lease payments under contractual commitments at March 31, 2014 are as follows (in thousands):
	Year Ending March 31,					Year Ending March 31,
	2015 (six months)	$	71,007			2015	$	133,170
	2016	106,384				2016	93,454
	2017	88,666				2017	64,209
	2018	74,265				2018	49,802
	2019	49,907				2019	29,213
	Thereafter	117,125				Thereafter	58,182
	Total	$	507,354			Total	$	428,030
Schedule of future minimum throughput payments under agreements	Future minimum throughput payments under these agreements at September 30, 2014 are as follows (in thousands):
	Year Ending March 31,
	2015 (six months)	$	41,822
	2016	95,050
	2017	82,916
	2018	62,565
	2019	51,278
	Thereafter	107,537
	Total	$	441,168
Schedule of commitments outstanding						At March 31, 2014, we had the following such commitments outstanding:
		Volume		Value			Volume		Value
		(in thousands)					(in thousands)
	Natural gas liquids fixed-price purchase commitments (gallons)	88,574		$	102,000	Natural gas liquids fixed-price purchase commitments (gallons)	31,111		$	39,117
	Natural gas liquids index-price purchase commitments (gallons)	528,459		601,719		Natural gas liquids floating-price purchase commitments (gallons)	522,947		618,293
	Natural gas liquids fixed-price sale commitments (gallons)	278,391		351,137		Natural gas liquids fixed-price sale commitments (gallons)	63,944		77,682
	Natural gas liquids index-price sale commitments (gallons)	370,639		512,900		Natural gas liquids floating-price sale commitments (gallons)	272,495		395,095
	Crude oil index-price purchase commitments (barrels)	4,437		383,153		Crude oil fixed-price purchase commitments (barrels)	4,016		364,557
	Crude oil fixed-price sale commitments (barrels)	32		2,867		Crude oil fixed-price sale commitments (barrels)	3,574		324,765
	Crude oil index-price sale commitments (barrels)	3,920		337,528

Equity_Tables1

Equity (Tables)	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Equity
Schedule of restricted unit activity
	Unvested restricted units at March 31, 2014	1,311,100											Unvested restricted units at March 31, 2012	—
	Units granted	333,903											Units granted	1,684,400
	Units vested and issued	(438,009	)										Units vested and issued	(156,802	)
	Units withheld for employee taxes	(231,194	)										Units withheld for employee taxes	(61,698	)
	Units forfeited	(117,000	)										Units forfeited	(21,000	)
	Unvested restricted units at September 30, 2014	858,800											Unvested restricted units at March 31, 2013	1,444,900
													Units granted	494,000
													Units vested and issued	(296,269	)
													Units withheld for employee taxes	(122,531	)
													Units forfeited	(209,000	)
													Unvested restricted units at March 31, 2014	1,311,100
Summary of scheduled vesting of unvested restricted units
	Vesting Date	Number of Awards											Vesting Date	Number of Awards
	July 1, 2015	334,800											July 1, 2014	408,300
	July 1, 2016	314,000											January 1, 2015	4,000
	July 1, 2017	178,500											July 1, 2015	341,300
	July 1, 2018	31,500											January 1, 2016	4,000
	Unvested restricted units at September 30, 2014	858,800											July 1, 2016	322,500
													January 1, 2017	4,000
													July 1, 2017	192,500
													January 1, 2018	4,000
													July 1, 2018	30,500
													Total unvested units at March 31, 2014	1,311,100
Schedule of estimated equity-based expense to be recorded on the awards granted	We estimate that the future expense we will record on the unvested awards at September 30, 2014 will be as follows (in thousands), after taking into consideration an estimate of forfeitures of approximately 80,000 units.
	Year Ending March 31,
	2015 (six months)	$	6,343
	2016	11,516
	2017	7,262
	2018	2,237
	2019	249
	Total	$	27,607
Schedule of rollforward of the liability related to equity-based compensation	Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our condensed consolidated balance sheets (in thousands):												Following is a rollforward of the liability related to equity-based compensation, which is reported within accrued expenses and other payables on our consolidated balance sheets (in thousands):
	Balance at March 31, 2014	$	10,012										Balance at March 31, 2012	$	—
	Expense recorded	21,659											Expense recorded	10,138
	Value of units vested and issued	(18,763		)									Value of units vested and issued	(3,627		)
	Taxes paid on behalf of participants	(9,901		)									Taxes paid on behalf of participants	(1,468		)
	Balance at September 30, 2014	$	3,007										Balance at March 31, 2013	5,043
													Expense recorded	17,804
													Value of units vested and issued	(9,085		)
													Taxes paid on behalf of participants	(3,750		)
													Balance at March 31, 2014	$	10,012
Partnership Equity
Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner
																	Amount			Amount Paid to			Amount Paid to
													Date Declared	Record Date		Date Paid	Per Unit			Limited Partners			General Partner
																				(in thousands)			(in thousands)
													July 25, 2011	August 3, 2011		August 12, 2011	$	0.1669		$	2,467		$	3
													October 21, 2011	October 31, 2011		November 14, 2011	0.3375			4,990			5
													January 24, 2012	February 3, 2012		February 14, 2012	0.35			7,735			10
													April 18, 2012	April 30, 2012		May 15, 2012	0.3625			9,165			10
													July 24, 2012	August 3, 2012		August 14, 2012	0.4125			13,574			134
													October 17, 2012	October 29, 2012		November 14, 2012	0.45			22,846			707
													January 24, 2013	February 4, 2013		February 14, 2013	0.4625			24,245			927
													April 25, 2013	May 6, 2013		May 15, 2013	0.4775			25,605			1,189
													July 25, 2013	August 5, 2013		August 14, 2013	0.4938			31,725			1,739
													October 23, 2013	November 4, 2013		November 14, 2013	0.5113			35,908			2,491
													January 23, 2014	February 4, 20143		February 14, 2014	0.5313			42,150			4,283
													April 24, 2014	May 5, 2014		May 15, 2014	0.5513			43,737			5,754
TLP
Partnership Equity
Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner
									Marginal Percentage Interest In
		Total Quarterly							Distributions
		Distribution Per Unit							Unitholders		General Partner
	Minimum quarterly distribution						$	0.4	98	%	2	%
	First target distribution	above		$	0.4	up to	$	0.44	98	%	2	%
	Second target distribution	above		$	0.44	up to	$	0.5	85	%	15	%
	Third target distribution	above		$	0.5	up to	$	0.6	75	%	25	%
	Thereafter	above		$	0.6				50	%	50	%
Future Distribution Payments
Partnership Equity
Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner
									Marginal Percentage Interest In												Marginal Percentage Interest In
		Total Quarterly							Distributions					Total Quarterly							Distributions
		Distribution Per Unit							Unitholders		General Partner			Distribution per Unit							Unitholders		General Partner
	Minimum quarterly distribution						$	0.3375	99.9	%	0.1	%	Minimum quarterly distribution						$ 0.337500		99.9	%	0.1	%
	First target distribution	above		$	0.3375	up to	$	0.388125	99.9	%	0.1	%	First target distribution	above		$ 0.337500	up to		$ 0.388125		99.9	%	0.1	%
	Second target distribution	above		$	0.388125	up to	$	0.421875	86.9	%	13.1	%	Second target distribution	above		$ 0.388125	up to		$ 0.421875		86.9	%	13.1	%
	Third target distribution	above		$	0.421875	up to	$	0.50625	76.9	%	23.1	%	Third target distribution	above		$ 0.421875	up to		$ 0.506250		76.9	%	23.1	%
	Thereafter	above		$	0.50625				51.9	%	48.1	%	Thereafter	above		$ 0.506250					51.9	%	48.1	%

Fair_Value_of_Financial_Instru6

Fair Value of Financial Instruments (Tables)	6 Months Ended												12 Months Ended
	Sep. 30, 2014												Mar. 31, 2014
Fair Value of Financial Instruments
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 on the condensed consolidated balance sheet at September 30, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2014:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	48,632		$	(5,378	)					Level 1 measurements	$	4,990		$	(3,258	)
	Level 2 measurements		51,389			(38,280		)					Level 2 measurements	49,605			(43,303		)
			100,021			(43,658		)						54,595			(46,561		)
	Netting of counterparty contracts (1)		(4,635		)	4,635							Netting of counterparty contracts(1)	(4,347		)	4,347
	Cash collateral held		(13,704		)	—							Cash collateral provided or held	456			—
	Commodity derivatives on condensed consolidated balance sheet		$	81,682		$	(39,023	)					Commodity contracts reported on consolidated balance sheet	$	50,704		$	(42,214	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
	The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported on the condensed consolidated balance sheet at March 31, 2014:												The following table summarizes the estimated fair values of the commodity derivative assets (liabilities) reported on the consolidated balance sheet at March 31, 2013:
			Derivative			Derivative								Derivative			Derivative
			Assets			Liabilities								Assets			Liabilities
			(in thousands)											(in thousands)
	Level 1 measurements		$	4,990		$	(3,258	)					Level 1 measurements	$	947		$	(3,324	)
	Level 2 measurements		49,605			(43,303		)					Level 2 measurements	9,911			(13,280		)
			54,595			(46,561		)						10,858			(16,604		)
	Netting of counterparty contracts (1)		(4,347		)	4,347							Netting of counterparty contracts(1)	(3,503		)	3,503
	Net cash collateral provided		456			—							Cash collateral provided or held	(1,760		)	400
	Commodity derivatives on condensed consolidated balance sheet		$	50,704		$	(42,214	)					Commodity contracts reported on consolidated balance sheet	$	5,595		$	(12,701	)
	(1)     Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.												(1)         Relates to derivative assets and liabilities that are expected to be net settled on an exchange or through a master netting arrangement with the counterparty.
Schedule of location of commodity derivative assets and liabilities reported on the condensed consolidated balance sheets
			September 30,			March 31,								March 31,
			2014			2014								2014			2013
			(in thousands)											(in thousands)
	Prepaid expenses and other current assets		$	81,682		$	50,704						Prepaid expenses and other current assets	$	50,704		$	5,551
	Accrued expenses and other payables		(39,023		)	(42,214		)					Other noncurrent assets	—			44
	Net commodity derivative asset		$	42,659		$	8,490						Accrued expenses and other payables	(42,214		)	(12,701		)
													Net asset (liability)	$	8,490		$	(7,106	)
Summary of open commodity derivative contract positions
					Total		Fair Value						Contracts	Settlement Period		Total		Fair Value
					Notional		of									Notional		of Net Assets
					Units		Net Assets									Units		(Liabilities)
	Contracts		Settlement Period		(Barrels)		(Liabilities)									(Barrels)
					(in thousands)											(in thousands)
	At September 30, 2014 -												At March 31, 2014 -
	Cross-commodity (1)		October 2014 – March 2015		(12	)	$	(1,283	)				Cross-commodity (1)	April 2014 – March 2015		140		$	(1,876	)
	Crude oil fixed-price (2)		October 2014 – December 2015		(1,638	)	9,380						Crude oil fixed-price (2)	April 2014 – March 2015		(1,600	)	(2,796		)
	Crude oil index (3)		October 2014 – July 2015		2,195		4,397						Crude oil index (3)	April 2014 – December 2015		3,598		6,099
	Propane fixed-price (4)		October 2014 – March 2015		1,238		53						Propane fixed-price (4)	April 2014 – March 2015		60		1,753
	Refined products fixed-price (5)		October 2014 – July 2015		(4,475	)	38,712						Refined products fixed-price (5)	April 2014 – July 2014		732		560
	Renewable products fixed-price (6)		October 2014 – December 2015		(14	)	5,104						Renewable products fixed-price (6)	April 2014 – July 2014		106		4,084
							56,363						Other	April 2014		—		210
	Net cash collateral held						(13,704		)									8,034
	Net commodity derivatives on condensed consolidated balance sheet						$	42,659					Net cash collateral provided					456
													Net value of commodity derivatives on consolidated balance sheet					$	8,490
	At March 31, 2014 -
	Cross-commodity (1)		April 2014 – March 2015		140		$	(1,876	)				At March 31, 2013 -
	Crude oil fixed-price (2)		April 2014 – March 2015		(1,600	)	(2,796		)				Cross-commodity (1)	April 2013 - March 2014		430		$	(10,208	)
	Crude oil index (3)		April 2014 – December 2015		3,598		6,099						Crude oil fixed-price (2)	April 2013 - March 2014		(144	)	1,033
	Propane fixed-price (4)		April 2014 – March 2015		60		1,753						Crude oil index (3)	April 2013 - June 2014		(91	)	153
	Refined products fixed-price (5)		April 2014 – July 2014		732		560						Propane fixed-price (4)	April 2013 - March 2014		(282	)	3,197
	Renewable products fixed-price (6)		April 2014 – July 2014		106		4,084						Other	May 2013 - June 2013		8		79
	Other		April 2014		—		210											(5,746		)
							8,034						Net cash collateral held					(1,360		)
	Net cash collateral provided						456						Net value of commodity derivatives on consolidated balance sheet					$	(7,106	)
	Net commodity derivatives on condensed consolidated balance sheet						$	8,490
													(1)         Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as economic hedges against the risk of one commodity price moving relative to another commodity price.
	(1)     Cross-commodity — Our operating segments may purchase or sell a physical commodity where the underlying contract pricing mechanisms are tied to different commodity price indices. The contracts listed in this table as “Cross-commodity” represent derivatives we have entered into as an economic hedge against the risk of one commodity price moving relative to another commodity price.
													(2)         Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
	(2)     Crude oil fixed-price — Our crude oil logistics segment routinely purchases crude oil inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Crude oil fixed-price” represent derivatives we have entered into as an economic hedge against the risk that crude oil prices will decline while we are holding the inventory.
													(3)         Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
	(3)     Crude oil index — Our crude oil logistics segment may purchase or sell crude oil where the underlying contract pricing mechanisms are tied to different crude oil indices. These indices may vary in the type or location of crude oil, or in the timing of delivery within a given month. The contracts listed in this table as “Crude oil index” represent derivatives we have entered into as an economic hedge against the risk of one crude oil index moving relative to another crude oil index.
													(4)         Propane fixed-price — Our liquids segment routinely purchases inventory during the warmer months and stores the inventory for sale in the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
	(4)     Propane fixed-price — Our liquids segment routinely purchases propane inventory during the warmer months and stores the propane inventory for sale during the colder months. The contracts listed in this table as “Propane fixed-price” represent derivatives we have entered into as an economic hedge against the risk that propane prices will decline while we are holding the inventory.
													(5)         Refined products fixed-price — Our refined products segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
	(5)     Refined products fixed-price — Our refined products and renewables segment routinely purchases refined products inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Refined products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that refined product prices will decline while we are holding the inventory.
													(6)         Renewable products fixed-price — Our renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
	(6)     Renewable products fixed-price — Our refined products and renewables segment routinely purchases biodiesel and ethanol inventory to enable us to fulfill future orders expected to be placed by our customers. The contracts listed in this table as “Renewable products fixed-price” represent derivatives we have entered into as an economic hedge against the risk that biodiesel or ethanol prices will decline while we are holding the inventory.
Schedule of net gains (losses) from entity's commodity derivatives to cost of sales
	Three Months Ended						Six Months Ended						Year Ended March 31,
	September 30,						September 30,						2014	$	(43,655	)
	2014			2013			2014			2013			2013	(4,381		)
	(in thousands)												2012	5,676
	$	55,981		$	(10,672	)	$	38,496		$	(17,881	)
Schedule of estimates fair values of Fixed - Rate Notes	The following table provides estimates of the fair values of our fixed-rate notes at September 30, 2014 (in thousands):
	5.125% Notes due 2019		$	390,000
	6.875% Notes due 2021		475,000
	6.650% Notes due 2022		275,000

Segments_Tables1

Segments (Tables)	6 Months Ended													12 Months Ended
	Sep. 30, 2014													Mar. 31, 2014
Segments
Schedule of certain information related to the results of operations of each segment
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands)
		(in thousands)												Revenues:
	Revenues:													Crude oil logistics -
	Crude oil logistics -													Crude oil sales	$	4,559,923		$	2,322,706		$	—
	Crude oil sales	$	2,108,117		$	1,013,061		$	4,035,061		$	1,941,595		Crude oil transportation and other	36,469			16,442			—
	Crude oil transportation and other	13,082			9,794			25,196			19,729			Water solutions -
	Water solutions -													Water treatment and disposal	125,788			54,334			—
	Water treatment and disposal	47,572			28,823			89,288			47,511			Water transportation	17,312			7,893			—
	Water transportation	5,147			5,367			10,745			7,192			Liquids -
	Liquids -													Propane sales	1,632,948			841,448			923,022
	Propane sales	240,433			191,437			462,879			315,274			Other product sales	1,231,965			858,276			251,627
	Other product sales	306,625			308,606			594,984			558,459			Other revenues	31,062			33,954			2,462
	Other revenues	6,814			9,250			12,530			18,114			Retail propane -
	Retail propane -													Propane sales	388,225			288,410			175,417
	Propane sales	48,552			40,651			100,578			87,342			Distillate sales	127,672			106,192			6,547
	Distillate sales	11,530			10,562			30,225			28,431			Other revenues	35,918			35,856			17,370
	Other revenues	8,276			8,198			15,457			15,898			Refined products	1,180,895			—			—
	Refined products and renewables -													Renewables	176,781			—			—
	Refined products sales	2,489,795			—			3,476,018			—			Corporate and other	437,713			4,233			—
	Renewables sales	117,425			—			248,699			—			Eliminations of intersegment sales	(283,397		)	(151,977		)	(65,972		)
	Corporate and other	1,333			1,485			2,794			2,959			Total revenues	$	9,699,274		$	4,417,767		$	1,310,473
	Elimination of intersegment sales	(24,175		)	(33,297		)	(75,314		)	(62,610		)
	Total revenues	$	5,380,526		$	1,593,937		$	9,029,140		$	2,979,894			Year Ended March 31,
															2014			2013			2012
	Depreciation and Amortization:														(in thousands)
	Crude oil logistics	$	9,240		$	3,330		$	18,971		$	8,014		Depreciation and amortization:
	Water solutions	17,573			11,438			34,665			18,794			Crude oil logistics	$	22,111		$	9,176		$	—
	Liquids	3,384			2,672			6,585			5,376			Water solutions	55,105			20,923			—
	Retail propane	7,684			6,871			15,255			14,111			Liquids	11,018			11,085			3,661
	Refined products and renewables	11,917			—			12,761			—			Retail propane	28,878			25,496			11,450
	Corporate and other	301			750			1,237			1,490			Refined products	109			—			—
	Total depreciation and amortization	$	50,099		$	25,061		$	89,474		$	47,785		Renewables	516			—			—
														Corporate and other	3,017			2,173			—
	Operating Income (Loss):													Total depreciation and amortization	$	120,754		$	68,853		$	15,111
	Crude oil logistics	$	38		$	5,884		$	1,501		$	12,493
	Water solutions	14,792			2,913			13,885			5,956				Year Ended March 31,
	Liquids	10,929			14,605			10,016			12,490				2014			2013			2012
	Retail propane	(3,062		)	(4,520		)	(4,648		)	(6,024		)		(in thousands)
	Refined products and renewables	8,822			—			7,567			—			Operating income (loss):
	Corporate and other	(23,749		)	(8,937		)	(41,106		)	(22,312		)	Crude oil logistics	$	678		$	34,236		$	—
	Total operating income (loss)	$	7,770		$	9,945		$	(12,785	)	$	2,603		Water solutions	10,317			8,576			—
														Liquids	71,888			30,336			9,735
														Retail propane	61,285			46,869			9,616
														Refined products	4,080			—			—
														Renewables	2,434			—			—
														Corporate and other	(44,117		)	(32,710		)	(4,321		)
														Total operating income	$	106,565		$	87,307		$	15,030
Schedule of additions to property, plant and equipment for each segment
		Three Months Ended						Six Months Ended							Year Ended March 31,
		September 30,						September 30,							2014			2013			2012
		2014			2013			2014			2013				(in thousands)
		(in thousands)												Additions to property, plant and equipment, including acquisitions (accrual basis):
	Additions to property, plant and equipment:													Crude oil logistics	$	204,642		$	89,860		$	—
	Crude oil logistics	$	39,464		$	31,336		$	81,413		$	35,462		Water solutions	100,877			137,116			—
	Water solutions	40,610			62,473			48,072			70,182			Liquids	52,560			15,129			50,276
	Liquids	1,911			13,209			3,070			28,316			Retail propane	24,430			66,933			150,181
	Retail propane	9,567			4,546			12,411			11,492			Refined products	719			—			—
	Refined products and renewables	512,281			—			512,281			—			Renewables	519			—			—
	Corporate and other	1,809			217			3,262			846			Corporate and other	7,242			17,858			—
	Total	$	605,642		$	111,781		$	660,509		$	146,298		Total	$	390,989		$	326,896		$	200,457
Schedule of long-lived assets (consisting of net property, plant and equipment, net intangible assets and goodwill) and total assets by segment
		September 30,			March 31,										March 31,
		2014			2014													2013
		(in thousands)													2014			(Note 2)
	Total assets:														(in thousands)
	Crude oil logistics	$	2,079,380		$	1,723,812								Total assets:
	Water solutions	964,336			875,714									Crude oil logistics	$	1,723,812		$	801,351
	Liquids	756,133			577,795									Water solutions	875,714			466,412
	Retail propane	506,958			541,832									Liquids	577,795			474,141
	Refined products and renewables	2,183,674			303,230									Retail propane	541,832			513,301
	Corporate and other	61,198			144,840									Refined products	157,581			—
	Total	$	6,551,679		$	4,167,223								Renewables	145,649			—
														Corporate and other	144,840			36,413
	Long-lived assets, net:													Total	$	4,167,223		$	2,291,618
	Crude oil logistics	$	996,615		$	980,978
	Water solutions	910,467			848,479									Long-lived assets, net:
	Liquids	271,567			274,846									Crude oil logistics	$	980,978		$	357,230
	Retail propane	436,621			438,324									Water solutions	848,479			453,909
	Refined products and renewables	772,916			60,720									Liquids	274,846			238,192
	Corporate and other	53,705			47,961									Retail propane	438,324			441,762
	Total	$	3,441,891		$	2,651,308								Refined products	27,017			—
														Renewables	33,703			—
														Corporate and other	47,961			31,996
														Total	$	2,651,308		$	1,523,089

Transactions_with_Affiliates_T1

Transactions with Affiliates (Tables)	6 Months Ended									12 Months Ended
	Sep. 30, 2014									Mar. 31, 2014
Transactions with Affiliates
Summary of purchase and sales transactions of products and services
		Three Months Ended				Six Months Ended					Year Ended March 31,
		September 30,				September 30,					2014		2013		2012
		2014		2013		2014		2013			(in thousands)
		(in thousands)								Sales to SemGroup	$	306,780	$	32,431	$	29,200
	Sales to SemGroup	$	43,427	$	3,780	$	117,233	$	3,780	Purchases from SemGroup	445,951		60,425		23,800
	Purchases from SemGroup	45,730		28,377		118,997		47,916		Sales to entities affiliated with management	110,824		16,828		—
	Purchases from equity method investees	34,689		—		70,965		—		Purchases from entities affiliated with management	120,038		60,942		—
	Sales to equity method investees	9,131		—		9,131		—
	Sales to entities affiliated with management	1,706		58,769		1,854		109,872
	Purchases from entities affiliated with management	3,845		48,522		6,984		56,346
Schedule of receivables from affiliates
		September 30,		March 31,							March 31,
		2014		2014							2014		2013
		(in thousands)									(in thousands)
	Receivables from SemGroup	$	39,331	$	7,303					Receivables from entities affiliated with management	$	142	$	22,883
	Receivables from entities affiliated with management	1,705		142						Receivables from SemGroup	7,303		—
	Receivables from equity method investees	670		—							$	7,445	$	22,883
	Total	$	41,706	$	7,445
Schedule of payables to affiliates
		September 30,		March 31,							March 31,
		2014		2014							2014		2013
		(in thousands)									(in thousands)
	Payables to SemGroup	$	44,015	$	27,738					Payables to SemGroup	$	76,192	$	4,601
	Payables to equity method investees	39,549		48,454						Payables to entities affiliated with management	654		2,299
	Payables to entities affiliated with management	1,743		654							$	76,846	$	6,900
	Total	$	85,307	$	76,846

Condensed_Consolidating_Guaran7

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Tables)	6 Months Ended																			12 Months Ended
	Sep. 30, 2014																			Mar. 31, 2014
Condensed Consolidating Guarantor and Non-Guarantor Financial Information
Schedule of Condensed Consolidating Balance Sheets
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Balance Sheet																			Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		September 30, 2014																			March 31, 2014
		NGL Energy			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
		Partners LP																			Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	ASSETS																			ASSETS
	CURRENT ASSETS:																			CURRENT ASSETS:
	Cash and cash equivalents	$	2,841		$	—		$	7,823		$	1,159		$	—		$	11,823		Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			1,419,442			13,675			—			1,433,117			Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904
	Accounts receivable - affiliates	—			—			41,035			671			—			41,706			Accounts receivable - affiliates	—			—			7,445			—			—			7,445
	Inventories	—			—			937,814			3,775			—			941,589			Inventories	—			—			306,434			3,726			—			310,160
	Prepaid expenses and other current assets	—			—			155,332			1,486			—			156,818			Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	2,841			—			2,561,446			20,766			—			2,585,053			Total current assets	1,181			—			1,290,690			17,428			—			1,309,299
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			863,694			569,619			—			1,433,313			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346
	GOODWILL	—			—			1,139,374			31,116			—			1,170,490			GOODWILL	—			—			1,105,008			1,998			—			1,107,006
	INTANGIBLE ASSETS, net of accumulated amortization	1,307			17,619			778,960			40,202			—			838,088			INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956
	INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			214,234			268,410			—			482,644			INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821
	NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893			849,526			(1,026,605		)	(71,814		)	—			—			NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—
	INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573			—			10,470			—			(1,754,043		)	—			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
	OTHER NONCURRENT ASSETS	—			—			40,035			2,056			—			42,091			OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795
	Total assets	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679		Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	LIABILITIES AND EQUITY																			LIABILITIES AND EQUITY
	CURRENT LIABILITIES:																			CURRENT LIABILITIES:
	Accounts payable - trade	$	—		$	—		$	1,333,780		$	11,244		$	—		$	1,345,024		Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211
	Accounts payable - affiliates	—			—			85,237			70			—			85,307			Accounts payable - affiliates	—			—			73,703			3,143			—			76,846
	Accrued expenses and other payables	554			19,021			186,226			12,681			—			218,482			Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690
	Advance payments received from customers	—			—			105,597			508			—			106,105			Advance payments received from customers	—			—			29,891			74			—			29,965
	Current maturities of long-term debt	—			—			5,004			58			—			5,062			Current maturities of long-term debt	—			—			7,058			22			—			7,080
	Total current liabilities	554			19,021			1,715,844			24,561			—			1,759,980			Total current liabilities	554			14,266			961,827			19,145			—			995,792
	LONG-TERM DEBT, net of current maturities	250,000			850,000			1,085,155			252,196			—			2,437,351			LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834
	OTHER NONCURRENT LIABILITIES	—			—			35,160			4,358			—			39,518			OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744
																				EQUITY
	EQUITY																			Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815
	Partners’ equity (deficit)	1,746,060			(1,876		)	1,745,450			579,312			(2,322,813		)	1,746,133			Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
	Accumulated other comprehensive loss	—			—			(1		)	(72		)	—			(73		)	Noncontrolling interests	—			—			—			—			5,274			5,274
	Noncontrolling interests	—			—			—			—			568,770			568,770			Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
	Total equity (deficit)	1,746,060			(1,876		)	1,745,449			579,240			(1,754,043		)	2,314,830			Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
	Total liabilities and equity	$	1,996,614		$	867,145		$	4,581,608		$	860,355		$	(1,754,043	)	$	6,551,679
																				(1)   The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)         The parent is a co-issuer of the 2019 Notes and 2021 Notes that are included in the NGL Energy Finance Corp. column.																			NGL ENERGY PARTNERS LP
																				Condensed Consolidating Balance Sheet
	NGL ENERGY PARTNERS LP																			(U.S. Dollars in Thousands)
	Condensed Consolidating Balance Sheet
	(U.S. Dollars in Thousands)																				March 31, 2013
																					NGL Energy
		March 31, 2014																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		NGL Energy																			(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						ASSETS
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated			CURRENT ASSETS:
	ASSETS																			Cash and cash equivalents	$	—		$	11,206		$	355		$	—		$	11,561
	CURRENT ASSETS:																			Accounts receivable - trade, net of allowance for doubtful accounts	—			561,560			1,197			—			562,757
	Cash and cash equivalents	$	1,181		$	—		$	8,728		$	531		$	—		$	10,440		Accounts receivable - affiliates	—			22,883			—			—			22,883
	Accounts receivable - trade, net of allowance for doubtful accounts	—			—			887,789			13,115			—			900,904			Inventories	—			126,024			871			—			126,895
	Accounts receivable - affiliates	—			—			7,445			—			—			7,445			Prepaid expenses and other current assets	—			37,784			107			—			37,891
	Inventories	—			—			306,434			3,726			—			310,160			Total current assets	—			759,457			2,530			—			761,987
	Prepaid expenses and other current assets	—			—			80,294			56			—			80,350
	Total current assets	1,181			—			1,290,690			17,428			—			1,309,299			PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			497,743			28,694			—			526,437
																				GOODWILL	—			553,222			1,998			—			555,220
	PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	—			—			764,014			65,332			—			829,346			INTANGIBLE ASSETS, net of accumulated amortization	717			439,365			1,350			—			441,432
	GOODWILL	—			—			1,105,008			1,998			—			1,107,006			NET INTERCOMPANY RECEIVABLES (PAYABLES)	237,736			(233,294		)	(4,442		)	—			—
	INTANGIBLE ASSETS, net of accumulated amortization	1,169			11,552			700,603			1,632			—			714,956			INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	895,779			20,371			—			(916,150		)	—
INVESTMENTS IN UNCONSOLIDATED ENTITIES	—			—			189,821			—			—			189,821			OTHER NONCURRENT ASSETS	—			6,542			—			—			6,542
NET INTERCOMPANY RECEIVABLES (PAYABLES)	327,281			437,714			(720,737		)	(44,258		)	—			—			Total assets	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,447,502			—			17,673			—			(1,465,175		)	—
OTHER NONCURRENT ASSETS	—			—			16,674			121			—			16,795			LIABILITIES AND EQUITY
Total assets	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223		CURRENT LIABILITIES:
																			Accounts payable - trade	$	—		$	534,164		$	1,891		$	—		$	536,055
LIABILITIES AND EQUITY																			Accounts payable - affiliates	—			6,900			—			—			6,900
CURRENT LIABILITIES:																			Accrued expenses and other payables	554			83,001			2,051			—			85,606
Accounts payable - trade	$	—		$	—		$	726,252		$	13,959		$	—		$	740,211		Advance payments received from customers	—			22,364			8			—			22,372
Accounts payable - affiliates	—			—			73,703			3,143			—			76,846			Current maturities of long-term debt	—			8,610			16			—			8,626
Accrued expenses and other payables	554			14,266			124,923			1,947			—			141,690			Total current liabilities	554			655,039			3,966			—			659,559
Advance payments received from customers	—			—			29,891			74			—			29,965
Current maturities of long-term debt	—			—			7,058			22			—			7,080			LONG-TERM DEBT, net of current maturities	250,000			490,433			3			—			740,436
Total current liabilities	554			14,266			961,827			19,145			—			995,792			OTHER NONCURRENT LIABILITIES	—			2,155			50			—			2,205
																			EQUITY
LONG-TERM DEBT, net of current maturities	250,000			450,000			929,754			80			—			1,629,834			Partners’ equity	883,678			895,779			26,087			(921,890		)	883,654
OTHER NONCURRENT LIABILITIES	—			—			9,663			81			—			9,744			Accumulated other comprehensive income	—			—			24			—			24
																			Noncontrolling interests	—			—			—			5,740			5,740
EQUITY																			Total equity	883,678			895,779			26,111			(916,150		)	889,418
Partners’ equity (deficit)	1,526,579			(15,000		)	1,462,691			22,994			(1,470,449		)	1,526,815			Total liabilities and equity	$	1,134,232		$	2,043,406		$	30,130		$	(916,150	)	$	2,291,618
Accumulated other comprehensive loss	—			—			(189		)	(47		)	—			(236		)
Noncontrolling interests	—			—			—			—			5,274			5,274
Total equity (deficit)	1,526,579			(15,000		)	1,462,502			22,947			(1,465,175		)	1,531,853
Total liabilities and equity	$	1,777,133		$	449,266		$	3,363,746		$	42,253		$	(1,465,175	)	$	4,167,223
(1)     The parent is a co-issuer of the 2021 Notes that are included in the NGL Energy Finance Corp. column.
Schedule of Condensed Consolidating Statements of Operations	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			Condensed Consolidating Statement of Operations
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	REVENUES	$	—		$	—		$	5,325,186		$	55,364		$	(24	)	$	5,380,526		REVENUES	$	—		$	—		$	9,560,124		$	139,519		$	(369	)	$	9,699,274
	COST OF SALES	—			—			5,161,935			17,554			(24		)	5,179,465			COST OF SALES	—			—			9,011,011			122,057			(369		)	9,132,699
	OPERATING COSTS AND EXPENSES:																			OPERATING COSTS AND EXPENSES:
	Operating	—			—			84,300			17,253			—			101,553			Operating	—			—			253,214			6,182			—			259,396
	General and administrative	—			—			36,360			5,279			—			41,639			General and administrative	—			—			77,756			2,104			—			79,860
	Depreciation and amortization	—			—			38,999			11,100			—			50,099			Depreciation and amortization	—			—			117,573			3,181			—			120,754
	Operating Income	—			—			3,592			4,178			—			7,770			Operating Income	—			—			100,570			5,995			—			106,565
	OTHER INCOME (EXPENSE):																			OTHER INCOME (EXPENSE):
	Earnings of unconsolidated entities	—			—			2,310			1,387			—			3,697			Earnings from unconsolidated entities	—			—			1,898			—			—			1,898
	Interest expense	(4,067		)	(13,134		)	(9,956		)	(1,506		)	12			(28,651		)	Interest expense	(16,818		)	(15,000		)	(27,031		)	(51		)	46			(58,854		)
	Other, net	—			—			(524		)	(81		)	(12		)	(617		)	Other, net	—			—			202			(70		)	(46		)	86
	Income (Loss) Before Income Taxes	(4,067		)	(13,134		)	(4,578		)	3,978			—			(17,801		)	Income (Loss) Before Income Taxes	(16,818		)	(15,000		)	75,639			5,874			—			49,695
	INCOME TAX (PROVISION) BENEFIT	—			—			1,951			(29		)	—			1,922			INCOME TAX PROVISION	—			—			(937		)	—			—			(937		)
	EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(15,157		)	—			604			—			14,553			—			EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	64,473			—			4,771			—			(69,244		)	—
	Net Income (Loss)	(19,224		)	(13,134		)	(2,023		)	3,949			14,553			(15,879		)	Net Income (Loss)	47,655			(15,000		)	79,473			5,874			(69,244		)	48,758
	LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(11,056		)	(11,056		)	NET INCOME ALLOCATED TO GENERAL PARTNER													(14,148		)	(14,148		)
	LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,345		)	(3,345		)	NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(1,103		)	(1,103		)
	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	152		$	(30,280	)	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(84,495	)	$	33,507
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			Condensed Consolidating Statement of Operations
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2013																			Year Ended March 31, 2013
		NGL Energy																			NGL Energy
		Partners LP			Guarantor			Non-Guarantor			Consolidating										Partners LP			Guarantor			Non-Guarantor			Consolidating
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated							(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	REVENUES	$	—		$	1,546,226		$	47,735		$	(24	)	$	1,593,937					REVENUES	$	—		$	4,409,198		$	8,878		$	(309	)	$	4,417,767
	COST OF SALES	—			1,445,442			43,432			(24		)	1,488,850						COST OF SALES	—			4,038,251			1,168			(309		)	4,039,110
	OPERATING COSTS AND EXPENSES:																			OPERATING COSTS AND EXPENSES:
	Operating	—			52,979			2,790			—			55,769						Operating	—			164,944			4,855			—			169,799
	General and administrative	—			14,089			223			—			14,312						General and administrative	—			52,461			237			—			52,698
	Depreciation and amortization	—			23,970			1,091			—			25,061						Depreciation and amortization	—			66,916			1,937			—			68,853
	Operating Income	—			9,746			199			—			9,945						Operating Income	—			86,626			681			—			87,307
	OTHER INCOME (EXPENSE):																			OTHER INCOME (EXPENSE):
	Interest expense	(4,179		)	(6,880		)	(13		)	12			(11,060		)				Interest expense	(13,041		)	(19,951		)	(48		)	46			(32,994		)
	Other, net	—			528			(97		)	(12		)	419						Loss on early extinguishment of debt	—			(5,769		)	—			—			(5,769		)
																				Other, net	—			1,666			(99		)	(46		)	1,521
	Income (Loss) Before Income Taxes	(4,179		)	3,394			89			—			(696		)
																				Income (Loss) Before Income Taxes	(13,041		)	62,572			534			—			50,065
	INCOME TAX PROVISION	—			(236		)	—			—			(236		)
																				INCOME TAX PROVISION	—			(1,875		)	—			—			(1,875		)
	EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	3,238			80			—			(3,318		)	—
																				EQUITY IN NET INCOME OF CONSOLIDATED SUBSIDIARIES	60,981			284			—			(61,265		)	—
	Net Income (Loss)	(941		)	3,238			89			(3,318		)	(932		)
																				Net Income	47,940			60,981			534			(61,265		)	48,190
	LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(2,451		)	(2,451		)
																				NET INCOME ALLOCATED TO GENERAL PARTNER										(2,917		)	(2,917		)
	LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(9		)	(9		)
																				NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(250		)	(250		)
	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(941	)	$	3,238		$	89		$	(5,778	)	$	(3,392	)
																				NET INCOME ALLOCATED TO LIMITED PARTNERS	$	47,940		$	60,981		$	534		$	(64,432	)	$	45,023
	NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Operations																			NGL ENERGY PARTNERS LP
	(U.S. Dollars in Thousands)																			Condensed Consolidating Statement of Operations
																				(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2014
		NGL Energy																			Year Ended March 31, 2012
	Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							NGL Energy
	(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				Partners LP			Guarantor			Non-Guarantor			Consolidating
																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
REVENUES	$	—		$	—		$	8,952,772		$	76,421		$	(53	)	$	9,029,140
																			REVENUES	$	—		$	1,310,473		$	225		$	(225	)	$	1,310,473
COST OF SALES	—			—			8,676,881			36,690			(53		)	8,713,518
																			COST OF SALES	—			1,217,248			—			(225		)	1,217,023
OPERATING COSTS AND EXPENSES:
Operating	—			—			150,919			18,502			—			169,421			OPERATING COSTS AND EXPENSES:
General and administrative	—			—			64,124			5,388			—			69,512			Operating	—			47,162			138			—			47,300
Depreciation and amortization	—			—			77,545			11,929			—			89,474			General and administrative	—			15,823			186			—			16,009
																			Depreciation and amortization	—			14,964			147			—			15,111
Operating Income (Loss)	—			—			(16,697		)	3,912			—			(12,785		)
																			Operating Income (Loss)	—			15,276			(246		)	—			15,030
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	—			—			4,875			1,387			—			6,262			OTHER INCOME (EXPENSE):
Interest expense	(8,313		)	(21,280		)	(18,058		)	(1,517		)	23			(49,145		)	Interest expense	—			(7,619		)	(46		)	45			(7,620		)
Other, net	—			—			(1,056		)	71			(23		)	(1,008		)	Other, net	—			1,100			—			(45		)	1,055
Income (Loss) Before Income Taxes	(8,313		)	(21,280		)	(30,936		)	3,853			—			(56,676		)	Income (Loss) Before Income Taxes	—			8,757			(292		)	—			8,465
INCOME TAX (PROVISION) BENEFIT	—			—			993			(106		)	—			887			INCOME TAX PROVISION	—			(601		)	—			—			(601		)
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(50,886		)	—			337			—			50,549			—			EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	7,876			(280		)	—			(7,596		)	—
Net Income (Loss)	(59,199		)	(21,280		)	(29,606		)	3,747			50,549			(55,789		)	Net Income (Loss)	7,876			7,876			(292		)	(7,596		)	7,864
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER													(20,437		)	(20,437		)	NET INCOME ALLOCATED TO GENERAL PARTNER										(8		)	(8		)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS													(3,410		)	(3,410		)	NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS										12			12
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	26,702		$	(79,636	)	NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	7,876		$	7,876		$	(292	)	$	(7,592	)	$	7,868
(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
NGL ENERGY PARTNERS LP
Condensed Consolidating Statement of Operations
(U.S. Dollars in Thousands)
	Six Months Ended September 30, 2013
	NGL Energy
	Partners LP			Guarantor			Non-Guarantor			Consolidating
	(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
REVENUES	$	—		$	2,914,531		$	65,421		$	(58	)	$	2,979,894
COST OF SALES	—			2,735,890			56,094			(58		)	2,791,926
OPERATING COSTS AND EXPENSES:
Operating	—			99,710			5,104			—			104,814
General and administrative	—			32,297			469			—			32,766
Depreciation and amortization	—			46,000			1,785			—			47,785
Operating Income	—			634			1,969			—			2,603
OTHER INCOME (EXPENSE):
Interest expense	(8,368		)	(13,309		)	(28		)	23			(21,682		)
Other, net	—			627			(135		)	(23		)	469
Income (Loss) Before Income Taxes	(8,368		)	(12,048		)	1,806			—			(18,610		)
INCOME TAX BENEFIT	—			170			—			—			170
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	(10,206		)	1,672			—			8,534			—
Net Income (Loss)	(18,574		)	(10,206		)	1,806			8,534			(18,440		)
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER										(4,139		)	(4,139		)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS										(134		)	(134		)
NET INCOME (LOSS) ALLOCATED TO LIMITED PARTNERS	$	(18,574	)	$	(10,206	)	$	1,806		$	4,261		$	(22,713	)
Schedule of Condensed Consolidating Statements of Comprehensive Income (Loss)	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statements of Comprehensive Income (Loss)																			Condensed Consolidating Statements of Comprehensive Income (Loss)
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Three Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating							Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated				(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	Net income (loss)	$	(19,224	)	$	(13,134	)	$	(2,023	)	$	3,949		$	14,553		$	(15,879	)	Net income (loss)	$	47,655		$	(15,000	)	$	79,473		$	5,874		$	(69,244	)	$	48,758
	Other comprehensive income (loss)	—			—			4			(26		)	—			(22		)	Other comprehensive loss, net of tax	—			—			(189		)	(71		)	—			(260		)
	Comprehensive income (loss)	$	(19,224	)	$	(13,134	)	$	(2,019	)	$	3,923		$	14,553		$	(15,901	)	Comprehensive income (loss)	$	47,655		$	(15,000	)	$	79,284		$	5,803		$	(69,244	)	$	48,498
																				(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
																					Year Ended March 31, 2013
		Three Months Ended September 30, 2013																			NGL Energy
		NGL Energy																			Partners LP			Guarantor			Non-Guarantor			Consolidating
		Partners LP			Guarantor			Non-Guarantor			Consolidating										(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
																				Net income	$	47,940		$	60,981		$	534		$	(61,265	)	$	48,190
	Net income (loss)	$	(941	)	$	3,238		$	89		$	(3,318	)	$	(932	)
																				Other comprehensive loss, net of tax	—			—			(7		)	—			(7		)
	Other comprehensive loss	—			—			(5		)	—			(5		)
																				Comprehensive income	$	47,940		$	60,981		$	527		$	(61,265	)	$	48,183
	Comprehensive income (loss)	$	(941	)	$	3,238		$	84		$	(3,318	)	$	(937	)
																					Year Ended March 31, 2012
	NGL ENERGY PARTNERS LP																				NGL Energy
	Condensed Consolidating Statements of Comprehensive Income (Loss)																				Partners LP			Guarantor			Non-Guarantor			Consolidating
	(U.S. Dollars in Thousands)																				(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
		Six Months Ended September 30, 2014																		Net income (loss)	$	7,876		$	7,876		$	(292	)	$	(7,596	)	$	7,864
		NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor			Consolidating						Other comprehensive loss, net of tax	—			—			(25		)	—			(25		)
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Adjustments			Consolidated
																				Comprehensive income (loss)	$	7,876		$	7,876		$	(317	)	$	(7,596	)	$	7,839
	Net income (loss)	$	(59,199	)	$	(21,280	)	$	(29,606	)	$	3,747		$	50,549		$	(55,789	)
	Other comprehensive income (loss)	—			—			189			(26		)	—			163
	Comprehensive income (loss)	$	(59,199	)	$	(21,280	)	$	(29,417	)	$	3,721		$	50,549		$	(55,626	)
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.
		Six Months Ended September 30, 2013
		NGL Energy
		Partners LP			Guarantor			Non-Guarantor			Consolidating
		(Parent)			Subsidiaries			Subsidiaries			Adjustments			Consolidated
	Net income (loss)	$	(18,574	)	$	(10,206	)	$	1,806		$	8,534		$	(18,440	)
	Other comprehensive loss	—			—			(30		)	—			(30		)
	Comprehensive income (loss)	$	(18,574	)	$	(10,206	)	$	1,776		$	8,534		$	(18,470	)
Schedule of Condensed Consolidating Statements of Cash Flows	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Cash Flows																			Condensed Consolidating Statement of Cash Flows
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2014																			Year Ended March 31, 2014
		NGL Energy																			NGL Energy
		Partners LP			NGL Energy			Guarantor			Non-Guarantor										Partners LP			NGL Energy			Guarantor			Non-Guarantor
		(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated							(Parent) (1)			Finance Corp.			Subsidiaries			Subsidiaries			Consolidated
	OPERATING ACTIVITIES:																			OPERATING ACTIVITIES:
	Net cash provided by (used in) operating activities	$	(8,180	)	$	(15,383	)	$	(56,019	)	$	17,947		$	(61,635	)				Net cash provided by (used in) operating activities	$	(16,625	)	$	—		$	99,754		$	2,107		$	85,236
	INVESTING ACTIVITIES:																			INVESTING ACTIVITIES:
	Purchases of long-lived assets	—			—			(81,710		)	(1,141		)	(82,851		)				Purchases of long-lived assets	—			—			(118,455		)	(46,693		)	(165,148		)
	Acquisitions of businesses, including acquired working capital, net of cash acquired	—			—			(657,514		)	(1,250		)	(658,764		)				Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,154		)	—			(932,373		)	(2,283		)	(1,268,810		)
	Cash flows from commodity derivatives	—			—			4,327			—			4,327						Cash flows from commodity derivatives	—			—			(35,956		)	—			(35,956		)
	Proceeds from sales of assets	—			—			8,741			—			8,741						Proceeds from sales of assets	—			—			12,884			11,776			24,660
	Investments in unconsolidated entities	—			—			(6,106		)	(20,284		)	(26,390		)				Investments in unconsolidated entities	—			—			(11,515		)	—			(11,515		)
	Distributions of capital from unconsolidated entities	—			—			2,774			1,875			4,649						Distributions of capital from unconsolidated entities	—			—			1,591			—			1,591
	Net cash used in investing activities	—			—			(729,488		)	(20,800		)	(750,288		)				Other	—			—			540			(735		)	(195		)
																				Net cash used in investing activities	(334,154		)	—			(1,083,284		)	(37,935		)	(1,455,373		)
	FINANCING ACTIVITIES:
	Proceeds from borrowings under revolving credit facilities	—			—			1,923,500			56,000			1,979,500						FINANCING ACTIVITIES:
	Payments on revolving credit facilities	—			—			(1,766,000		)	(38,000		)	(1,804,000		)				Proceeds from borrowings under revolving credit facilities	—			—			2,545,500			—			2,545,500
	Issuance of notes	—			400,000			—			—			400,000						Payments on revolving credit facilities	—			—			(2,101,000		)	—			(2,101,000		)
	Payments on other long-term debt	—			—			(4,173		)	(2		)	(4,175		)				Issuances of notes	—			450,000			—			—			450,000
	Debt issuance costs	(269		)	(7,209		)	(1,720		)	—			(9,198		)				Proceeds from borrowings on other long-term debt	—			—			780			100			880
	Contributions	395			—			—			—			395						Payments on other long-term debt	—			—			(8,802		)	(17		)	(8,819		)
	Distributions to owners	(111,008		)	—			—			—			(111,008		)				Debt issuance costs	(645		)	(12,286		)	(11,664		)	—			(24,595		)
	Distributions to noncontrolling interest partners	—			—			—			(8,654		)	(8,654		)				Contributions	765			—			—			2,060			2,825
	Proceeds from sale of common units, net of offering costs	370,446			—			—			—			370,446						Distributions	(145,090		)	—			—			(840		)	(145,930		)
	Net changes in advances with consolidated entities	(249,724		)	(377,408		)	632,995			(5,863		)	—						Proceeds from sale of common units, net of offering costs	650,155			—			—			—			650,155
	Net cash provided by financing activities	9,840			15,383			784,602			3,481			813,306						Net changes in advances with consolidated entities	(153,225		)	(437,714		)	556,238			34,701			—
	Net increase (decrease) in cash and cash equivalents	1,660			—			(905		)	628			1,383						Net cash provided by financing activities	351,960			—			981,052			36,004			1,369,016
	Cash and cash equivalents, beginning of period	1,181			—			8,728			531			10,440						Net increase (decrease) in cash and cash equivalents	1,181			—			(2,478		)	176			(1,121		)
	Cash and cash equivalents, end of period	$	2,841		$	—		$	7,823		$	1,159		$	11,823					Cash and cash equivalents, beginning of period	—			—			11,206			355			11,561
																				Cash and cash equivalents, end of period	$	1,181		$	—		$	8,728		$	531		$	10,440
	(1)     The parent is a co-issuer of the 2019 Notes and 2021 Notes.																			(1)         The parent is a co-issuer of the $450.0 million 6.875% Unsecured Notes that are included in the NGL Energy Finance Corp. column.
	NGL ENERGY PARTNERS LP																			NGL ENERGY PARTNERS LP
	Condensed Consolidating Statement of Cash Flows																			Condensed Consolidating Statement of Cash Flows
	(U.S. Dollars in Thousands)																			(U.S. Dollars in Thousands)
		Six Months Ended September 30, 2013																			Year Ended March 31, 2013
		NGL Energy																			NGL Energy
		Partners LP			Guarantor			Non-Guarantor													Partners LP			Guarantor			Non-Guarantor
		(Parent)			Subsidiaries			Subsidiaries			Consolidated										(Parent)			Subsidiaries			Subsidiaries			Consolidated
	OPERATING ACTIVITIES:																			OPERATING ACTIVITIES:
	Net cash provided by (used in) operating activities	$	(8,312	)	$	(44,607	)	$	4,175		$	(48,744	)							Net cash provided by (used in) operating activities	$	(12,428	)	$	140,794		$	4,268		$	132,634
	INVESTING ACTIVITIES:																			INVESTING ACTIVITIES:
	Purchases of long-lived assets	—			(37,180		)	(30,219		)	(67,399		)							Purchases of long-lived assets	—			(59,903		)	(12,572		)	(72,475		)
	Acquisitions of businesses, including acquired working capital, net of cash acquired	(334,085		)	(56,237		)	(2,283		)	(392,605		)							Acquisitions of businesses, including acquired working capital, net of cash acquired	(452,087		)	(38,718		)	—			(490,805		)
	Cash flows from commodity derivatives	—			(19,074		)	—			(19,074		)							Cash flows from commodity derivatives	—			11,579			—			11,579
	Proceeds from sales of assets	—			2,223			1			2,224									Proceeds from sales of assets	—			5,080			—			5,080
	Net cash used in investing activities	(334,085		)	(110,268		)	(32,501		)	(476,854		)							Net cash used in investing activities	(452,087		)	(81,962		)	(12,572		)	(546,621		)
	FINANCING ACTIVITIES:																			FINANCING ACTIVITIES:
	Proceeds from borrowings under revolving credit facility	—			1,061,500			—			1,061,500									Proceeds from borrowings under revolving credit facilities	—			1,227,975			—			1,227,975
	Payments on revolving credit facility	—			(893,000		)	—			(893,000		)							Payments on revolving credit facilities	—			(964,475		)	—			(964,475		)
	Proceeds from borrowings on other long-term debt	—			780			100			880									Issuance of notes	250,000			—			—			250,000
	Payments on other long-term debt	—			(4,499		)	(8		)	(4,507		)							Proceeds from borrowings on other long-term debt	—			634			19			653
	Debt issuance costs	(133		)	(2,085		)	—			(2,218		)							Payments on other long-term debt	—			(4,837		)	—			(4,837		)
	Contributions	504			—			1,940			2,444									Debt issuance costs	(777		)	(19,412		)	—			(20,189		)
	Distributions to owners	(60,258		)	—			(365		)	(60,623		)							Contributions	510			—			403			913
	Proceeds from sale of common units, net of offering costs	415,089			—			—			415,089									Distributions	(71,608		)	—			(74		)	(71,682		)
	Net changes in advances with consolidated entities	(11,459		)	(15,123		)	26,582			—									Proceeds from sale of common units, net of offering costs	(642		)	—			—			(642		)
	Net cash provided by financing activities	343,743			147,573			28,249			519,565									Net changes in advances with consolidated entities	286,991			(295,105		)	8,114			—
	Net increase (decrease) in cash and cash equivalents	1,346			(7,302		)	(77		)	(6,033		)							Net cash provided by (used in) financing activities	464,474			(55,220		)	8,462			417,716
	Cash and cash equivalents, beginning of period	—			11,206			355			11,561									Net increase (decrease) in cash and cash equivalents	(41		)	3,612			158			3,729
	Cash and cash equivalents, end of period	$	1,346		$	3,904		$	278		$	5,528								Cash and cash equivalents, beginning of period	41			7,594			197			7,832
																			Cash and cash equivalents, end of period	$	—		$	11,206		$	355		$	11,561
																			NGL ENERGY PARTNERS LP
																			Condensed Consolidating Statement of Cash Flows
																			(U.S. Dollars in Thousands)
																				Year Ended March 31, 2012
																				NGL Energy
																				Partners LP			Guarantor			Non-Guarantor
																				(Parent)			Subsidiaries			Subsidiaries			Consolidated
																			OPERATING ACTIVITIES:
																			Net cash provided by (used in) operating activities	$	—		$	90,477		$	(148	)	$	90,329
																			INVESTING ACTIVITIES:
																			Purchases of long-lived assets	—			(6,667		)	(877		)	(7,544		)
																			Acquisitions of businesses, including acquired working capital, net of cash acquired	(291,097		)	(6,304		)	—			(297,401		)
																			Cash flows from commodity derivatives	—			6,464			—			6,464
																			Proceeds from sales of assets	—			1,238			—			1,238
																			Other	—			346			—			346
																			Net cash used in investing activities	(291,097		)	(4,923		)	(877		)	(296,897		)
																			FINANCING ACTIVITIES:
																			Proceeds from borrowings under revolving credit facilities	—			478,900			—			478,900
																			Payments on revolving credit facilities	—			(329,900		)	—			(329,900		)
																			Payments on other long-term debt	—			(1,278		)	—			(1,278		)
																			Debt issuance costs	—			(2,380		)	—			(2,380		)
																			Contributions	—			—			440			440
																			Distributions	(19,060		)	—			—			(19,060		)
																			Proceeds from sale of common units, net of offering costs	74,759			—			—			74,759
																			Repurchase of common units	(3,418		)	—			—			(3,418		)
																			Net changes in advances with consolidated entities	238,816			(239,476		)	660			—
																			Net cash provided by (used in) financing activities	291,097			(94,134		)	1,100			198,063
																			Net increase (decrease) in cash and cash equivalents	—			(8,580		)	75			(8,505		)
																			Cash and cash equivalents, beginning of period	41			16,174			122			16,337
																			Cash and cash equivalents, end of period	$	41		$	7,594		$	197		$	7,832

Organization_and_Operations_De

Organization and Operations (Details)	0 Months Ended	6 Months Ended	12 Months Ended
	17-May-11	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
Organization and operations
Equity method ownership interest (as a percent)			50.00%
Ownership interest (as a percent)	0.10%	0.10%	0.10%	0.10%
TLP | General partner
Organization and operations
Ownership interest (as a percent)		2.00%
TLP | Limited partner
Organization and operations
Ownership interest (as a percent)		19.70%
Retail propane and distillate operations
Organization and operations
Number of owned terminals		22	22
Retail propane and distillate operations | Minimum
Organization and operations
Number of states in which entity operates		20	20
Refined products and renewables | BOSTCO
Organization and operations
Equity method ownership interest (as a percent)		42.50%
Refined products and renewables | Frontera
Organization and operations
Equity method ownership interest (as a percent)		50.00%
Crude oil logistics
Organization and operations
Equity method ownership interest (as a percent)		50.00%

Recovered_Sheet4

Significant Accounting Policies (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Supplemental cash flow information
Interest paid, exclusive of debt issuance costs and letter of credit fees	$10,445	$8,423	$36,429	$16,908	$31,827	$27,384	$4,966
Income taxes paid	1,241	369	2,246	650	1,639	1,027	430
Value of common units issued in business combinations		$80,619		$80,619

Recovered_Sheet5

Significant Accounting Policies (Details 2) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Inventories
Crude oil	$136,722	$156,473	$46,156
Natural gas liquids:
Propane	207,694	85,159	45,428
Butane	84,822	15,106
Other	11,390	14,490
Butane	27,091	3,945
Refined products:
Gasoline	219,111	15,597
Diesel	214,567	7,298
Other	11,390	14,490
Other	3,675	314
Renewables	36,517	11,778
Inventories	$941,589	$310,160	$126,895

Recovered_Sheet6

Significant Accounting Policies (Details 3) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Dec. 02, 2013	Dec. 31, 2013	Jul. 02, 2014
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)		50.00%
Carrying Value	$482,644,000	$189,821,000
Glass Mountain
Investments in Unconsolidated Entities
Carrying Value	189,847,000	181,488,000
Fair value in excess of historical net book value	70,000,000
Ethanol production facility
Investments in Unconsolidated Entities
Carrying Value	9,361,000	8,333,000
Water Supply Company
Investments in Unconsolidated Entities
Carrying Value	15,026,000
BOSTCO
Investments in Unconsolidated Entities
Carrying Value	244,092,000
Fair value in excess of historical net book value	24,000,000
Frontera
Investments in Unconsolidated Entities
Carrying Value	$24,318,000
Gavilon Energy
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)			11.00%
Gavilon Energy | Glass Mountain
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)			50.00%	50.00%
Gavilon Energy | Limited liability company
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)			11.00%	11.00%
TransMontaigne | BOSTCO
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)					42.50%
TransMontaigne | Frontera
Investments in Unconsolidated Entities
Equity method ownership interest (as a percent)					50.00%

Recovered_Sheet7

Significant Accounting Policies (Details 4) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Accrued Expenses and Other Payables
Accrued compensation and benefits	$49,146	$45,006	$27,252
Derivative liabilities	39,023	42,214	12,701
Product exchange liabilities	43,185	3,719	6,741
Accrued interest	23,945	18,668
Income and other tax liabilities	38,255	13,421	22,659
Other	24,928	18,662
Total accrued expenses and other payables	$218,482	$141,690	$85,606

Recovered_Sheet8

Significant Accounting Policies (Details 5)	0 Months Ended	6 Months Ended	12 Months Ended		0 Months Ended
	17-May-11	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Jul. 02, 2014
Noncontrolling Interests
Limited partners, interest (as a percent)		99.90%	99.90%	99.90%
General partner, interest (as a percent)	0.10%	0.10%	0.10%	0.10%
TLP
Noncontrolling Interests
Ownership interest acquired (as a percent)					19.70%
TLP
Noncontrolling Interests
Limited partners, interest (as a percent)					98.00%
General partner, interest (as a percent)					2.00%

Recovered_Sheet9

Earnings Per Unit (Details) (USD $)	3 Months Ended										6 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Earnings per unit
Net loss attributable to parent equity	-19,224		42,331	23,898	($941)	-17,633	22,341	40,176	10,073	-24,650	($59,199)	($18,574)	$47,655	$47,940	$7,876
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056				-2,451						-20,437	-4,139	-14,148	-2,917	-8
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280				-3,392						-79,636	-22,713	33,507	45,023	7,868
Common unitholders
Earnings per unit
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280				-2,830						-75,623	-19,637	31,614	39,517	4,859
Weighted average units outstanding (in shares)	88,331,653		73,421,309	67,941,726	58,909,389	47,703,313	47,665,015	46,364,381	44,831,836	26,529,133	81,267,742	53,336,969	61,970,471	41,353,574	15,169,983
Basic and diluted loss per unit (in dollars per share)	-0.34				($0.05)						($0.93)	($0.37)	$0.51	$0.96	$0.32
Subordinated unitholders
Earnings per unit
NET LOSS ALLOCATED TO LIMITED PARTNERS					$562						$4,013	$3,076	$1,893	$5,506	$3,009
Weighted average units outstanding (in shares)	5,919,346		5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346	5,919,346		5,919,346	5,919,346	5,919,346	5,175,384
Basic and diluted loss per unit (in dollars per share)		($0.68)			($0.09)							($0.52)	$0.32	$0.93	$0.58

Acquisitions_Details1

Acquisitions (Details) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended			0 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Jul. 02, 2014	Mar. 31, 2011	Jun. 19, 2012
Acquisitions
Purchase price, net of cash acquired										$658,764,000	$392,605,000	$1,268,810,000	$490,805,000	$297,401,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	1,170,490,000	1,107,006,000				555,220,000				1,170,490,000		1,107,006,000	555,220,000	167,245,000		8,568,000
Expense related to incentive compensation										21,659,000		17,804,000	10,138,000
Revenues	5,380,526,000	3,975,935,000	2,743,445,000	1,593,937,000	1,385,957,000	1,617,613,000	1,338,208,000	1,135,510,000	326,436,000	9,029,140,000	2,979,894,000	9,699,274,000	4,417,767,000	1,310,473,000
Operating income (loss)	7,770,000			9,945,000						-12,785,000	2,603,000	106,565,000	87,307,000	15,030,000
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment																	17,851,000
TransMontaigne Inc
Acquisitions
Purchase price, net of cash acquired															174,200,000
Inventory purchased	426,913,000									426,913,000
Amount paid for inventory purchased															346,900,000
Working capital settlement payment															33,500,000
Estimated additional amount to be paid on completion of working capital settlement process	27,500,000									27,500,000
Estimated fair values of the assets acquired and liabilities assumed
Cash and cash equivalents	1,469,000									1,469,000
Accounts receivable - trade	197,349,000									197,349,000
Accounts receivable - affiliates	528,000									528,000
Inventories	426,913,000									426,913,000
Prepaid expenses and other current assets	15,373,000									15,373,000
Goodwill	29,118,000									29,118,000
Equity method investments	250,000,000									250,000,000
Other noncurrent assets	3,911,000									3,911,000
Accounts payable - trade	-140,597,000									-140,597,000
Accounts payable - affiliates	-69,000									-69,000
Accrued expenses and other payables	-73,565,000									-73,565,000
Advance payments received from customers	-1,919,000									-1,919,000
Long-term debt	-234,000,000									-234,000,000
Other noncurrent liabilities	-34,856,000									-34,856,000
Noncontrolling interest	-567,120,000									-567,120,000
Fair value of net assets acquired	554,535,000									554,535,000
Accrual related to crude oil contracts	2,500,000									2,500,000
Expense related to termination benefits	2,700,000
Revenues	1,100,000,000									1,100,000,000
Operating income (loss)	-300,000									-300,000
Proposed exchange ratio of the company's common units for each outstanding unit of acquiree	1									1
TransMontaigne Inc | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	50,000,000									50,000,000
Useful life of intangible assets										7 years
TransMontaigne Inc | Pipeline capacity rights
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	87,000,000									87,000,000
Useful life of intangible assets										30 years
TransMontaigne Inc | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets	5,000,000									5,000,000
TransMontaigne Inc | Refined products terminal assets
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	418,405,000									418,405,000
Useful life of property, plant and equipment										20 years
TransMontaigne Inc | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	10,339,000									10,339,000
Useful life of property, plant and equipment										20 years
TransMontaigne Inc | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	28,666,000									28,666,000
Useful life of property, plant and equipment										20 years
TransMontaigne Inc | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,565,000									1,565,000
TransMontaigne Inc | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	56,095,000									56,095,000
TransMontaigne Inc | Information technology equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	7,851,000									7,851,000
TransMontaigne Inc | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	12,592,000									12,592,000
TransMontaigne Inc | Construction in progress
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	4,487,000									4,487,000
TransMontaigne Inc | General partner
Acquisitions
Ownership interest acquired (as a percent)															2.00%
TransMontaigne Inc | Limited partner
Acquisitions
Ownership interest acquired (as a percent)															19.70%
Previous owner of TransMontaigne
Acquisitions
Inventory purchased															380,400,000
Estimated fair values of the assets acquired and liabilities assumed
Inventories															$380,400,000
TLP
Acquisitions
Ownership interest acquired (as a percent)															19.70%

Acquisitions_Details_21

Acquisitions (Details 2) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended			1 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Jul. 31, 2014	Mar. 31, 2011
															item
Acquisitions
Cash paid for water facilities													$14,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	1,170,490	1,107,006				555,220				1,170,490		1,107,006	555,220	167,245		8,568
Revenues	5,380,526	3,975,935	2,743,445	1,593,937	1,385,957	1,617,613	1,338,208	1,135,510	326,436	9,029,140	2,979,894	9,699,274	4,417,767	1,310,473
Operating Income	7,770			9,945						-12,785	2,603	106,565	87,307	15,030
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										30 years		30 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years		3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years		40 years
Water Solutions Facilities
Acquisitions
Number of water disposal facilities acquired	4									4
Ownership interest acquired (as a percent)															75.00%
Number of additional water disposal facilities acquired															1
Cash paid for water facilities										82,900
Number of combined water disposal facilities acquired										5
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade	939									939
Inventories	253									253
Prepaid expenses and other current assets	62									62
Goodwill	57,777									57,777
Other noncurrent assets	50									50
Accounts payable - trade	-58									-58
Accrued expenses and other payables	-1,092									-1,092
Other noncurrent liabilities	-149									-149
Noncontrolling interest	-1,620									-1,620
Fair value of net assets acquired	82,870									82,870
Revenues										7,100
Operating Income										1,500
Water Solutions Facilities | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	23,066									23,066
Water Solutions Facilities | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										5 years
Water Solutions Facilities | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										40 years
Water Solutions Facilities | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	2,599									2,599
Water Solutions Facilities | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										3 years
Water Solutions Facilities | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment										7 years
Water Solutions Facilities | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	1,010									1,010
Water Solutions Facilities | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment	$33									$33
Useful life of property, plant and equipment										7 years

Acquisitions_Details_31

Acquisitions (Details 3) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended	0 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014	Jun. 09, 2014
	item	item	item
Acquisitions
Number of business combination agreements	2
Cash paid	$14,000
Retail propane
Acquisitions
Number of business combination agreements		3	4
Cash paid		6,400
Water Supply Company
Acquisitions
Cash paid				$15,000

Acquisitions_Details_41

Acquisitions (Details 4) (USD $)	12 Months Ended		6 Months Ended	0 Months Ended
	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Dec. 02, 2013	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012	Dec. 31, 2013
Acquisitions
Cash paid, net of cash acquired	$14,000,000
Equity method ownership interest (as a percent)		50.00%
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220,000	1,107,006,000	1,170,490,000		167,245,000	8,568,000
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment							17,851,000
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Information technology equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Information technology equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		7 years	7 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Gavilon Energy
Acquisitions
Cash paid, net of cash acquired				832,400,000
Equity method ownership interest (as a percent)				11.00%
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		349,529,000	326,484,000
Accounts receivable - affiliates		2,564,000	2,564,000
Inventories		107,430,000	107,430,000
Prepaid expenses and other current assets		68,322,000	68,322,000
Goodwill		359,169,000	342,769,000
Investments in unconsolidated entities		178,000,000	183,000,000
Other noncurrent assets		9,918,000	2,287,000
Accounts payable - trade		-342,792,000	-342,792,000
Accounts payable - affiliates		-2,585,000	-2,585,000
Accrued expenses and other payables		-70,999,000	-49,447,000
Advance payments received from customers		-10,667,000	-10,667,000
Other noncurrent liabilities		-44,740,000	-46,056,000
Fair value of net assets acquired		832,448,000	832,448,000
Bonus expense recorded during the period			5,200,000
Additional bonus expense expected			1,600,000
Gavilon Energy | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		349,529,000
Accounts receivable - affiliates		2,564,000
Inventories		107,430,000
Prepaid expenses and other current assets		68,322,000
Goodwill		359,169,000
Investments in unconsolidated entities		178,000,000
Other noncurrent assets		9,918,000
Accounts payable - trade		-342,792,000
Accounts payable - affiliates		-2,585,000
Accrued expenses and other payables		-70,999,000
Advance payments received from customers		-10,667,000
Other noncurrent liabilities		-44,740,000
Fair value of net assets acquired		832,448,000
Gavilon Energy | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-23,045,000
Goodwill			-16,400,000
Investments in unconsolidated entities			5,000,000
Other noncurrent assets			-7,631,000
Accrued expenses and other payables			-21,552,000
Other noncurrent liabilities			-1,316,000
Gavilon Energy | Crude oil storage lease commitments
Estimated fair values of the assets acquired and liabilities assumed
Liability recorded in the acquisition accounting		12,900,000	15,900,000	13,900,000
Amortization of contract liabilities through cost of sales		2,900,000	5,000,000
Future amortization
2015 (six months)			3,670,000
2016		3,260,000	4,040,000
2017		300,000	360,000
Gavilon Energy | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		101,600,000	107,950,000
Gavilon Energy | Customer relationships | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		101,600,000
Gavilon Energy | Customer relationships | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			6,350,000
Gavilon Energy | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		10 years	10 years
Gavilon Energy | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		20 years	20 years
Gavilon Energy | Lease Agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		8,700,000	8,700,000
Gavilon Energy | Lease Agreements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		8,700,000
Gavilon Energy | Lease Agreements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		1 year	1 year
Gavilon Energy | Lease Agreements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets		5 years	5 years
Gavilon Energy | Pipeline capacity rights
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			7,800,000
Gavilon Energy | Pipeline capacity rights | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			7,800,000
Gavilon Energy | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		791,000	327,000
Useful life of property, plant and equipment		3 years	3 years
Gavilon Energy | Vehicles | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		791,000
Gavilon Energy | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-464,000
Gavilon Energy | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		77,429,000	83,797,000
Gavilon Energy | Crude oil tanks and related equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		77,429,000
Gavilon Energy | Crude oil tanks and related equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			6,368,000
Gavilon Energy | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Gavilon Energy | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Gavilon Energy | Information technology equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		4,046,000	4,049,000
Gavilon Energy | Information technology equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		4,046,000
Gavilon Energy | Information technology equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			3,000
Gavilon Energy | Information technology equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Gavilon Energy | Information technology equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		7 years	7 years
Gavilon Energy | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		7,716,000	7,817,000
Gavilon Energy | Buildings and leasehold improvements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		7,716,000
Gavilon Energy | Buildings and leasehold improvements | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			101,000
Gavilon Energy | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Gavilon Energy | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Gavilon Energy | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		6,427,000	6,427,000
Gavilon Energy | Land | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		6,427,000
Gavilon Energy | Tank bottoms
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			16,930,000
Gavilon Energy | Tank bottoms | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		15,230,000
Gavilon Energy | Tank bottoms | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,700,000
Gavilon Energy | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		170,000	162,000
Useful life of property, plant and equipment		7 years	7 years
Gavilon Energy | Other | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		170,000
Gavilon Energy | Other | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-8,000
Gavilon Energy | Construction in progress
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		7,190,000	7,180,000
Goodwill				29,000,000
Gavilon Energy | Construction in progress | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		7,190,000
Gavilon Energy | Construction in progress | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-10,000
Gavilon Energy | Glass Mountain
Acquisitions
Equity method ownership interest (as a percent)				50.00%				50.00%

Acquisitions_Details_51

Acquisitions (Details 5) (USD $)	12 Months Ended		6 Months Ended	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Aug. 02, 2013	Mar. 31, 2012	Mar. 31, 2011
Acquisitions
Cash paid, net of cash acquired	$14,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220	1,107,006	1,170,490		167,245	8,568
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Oilfield Water Lines LP
Acquisitions
Number of common units issued to acquire business (in shares)		2,463,287		2,463,287
Value of common units issued		68,557		68,600
Cash paid, net of cash acquired		167,732		167,700
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		7,268	6,837
Inventories		154	154
Prepaid expenses and other current assets		402	402
Goodwill		89,699	90,144
Accounts payable - trade		-6,469	-6,469
Accrued expenses and other payables		-992	-992
Other noncurrent liabilities		-64	-64
Fair value of net assets acquired		236,289	236,289
Oilfield Water Lines LP | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		7,268
Inventories		154
Prepaid expenses and other current assets		402
Goodwill		89,699
Accounts payable - trade		-6,469
Accrued expenses and other payables		-992
Other noncurrent liabilities		-64
Fair value of net assets acquired		236,289
Oilfield Water Lines LP | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-431
Goodwill			445
Oilfield Water Lines LP | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		110,000	110,000
Useful life of intangible assets		10 years
Oilfield Water Lines LP | Customer relationships | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		110,000
Oilfield Water Lines LP | Customer relationships | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets			8 years
Oilfield Water Lines LP | Customer relationships | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets			10 years
Oilfield Water Lines LP | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		2,000	2,000
Useful life of intangible assets		2 years 6 months	3 years
Oilfield Water Lines LP | Non-compete agreements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		2,000
Oilfield Water Lines LP | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		8,157	8,143
Oilfield Water Lines LP | Vehicles | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		8,157
Oilfield Water Lines LP | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-14
Oilfield Water Lines LP | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Oilfield Water Lines LP | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		10 years	10 years
Oilfield Water Lines LP | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		23,173	23,173
Oilfield Water Lines LP | Water treatment facilities and equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		23,173
Oilfield Water Lines LP | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Oilfield Water Lines LP | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Oilfield Water Lines LP | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,198	2,198
Oilfield Water Lines LP | Buildings and leasehold improvements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,198
Oilfield Water Lines LP | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		7 years	7 years
Oilfield Water Lines LP | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Oilfield Water Lines LP | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		710	710
Oilfield Water Lines LP | Land | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		710
Oilfield Water Lines LP | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		53	53
Oilfield Water Lines LP | Other | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		53
Oilfield Water Lines LP | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Oilfield Water Lines LP | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years

Acquisitions_Details_61

Acquisitions (Details 6) (USD $)	12 Months Ended		6 Months Ended	3 Months Ended	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Sep. 30, 2013	Mar. 01, 2014	Mar. 02, 2014	Mar. 31, 2012	Mar. 31, 2011
	item
Acquisitions
Number of business acquired	2
Cash paid, net of cash acquired	$14,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220	1,107,006	1,170,490				167,245	8,568
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Other Water Solutions
Acquisitions
Number of business acquired		2
Value of common units issued		6,800
Cash paid, net of cash acquired		151,600
Number of common units issued to acquire business (in shares)				222,381
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			2,146
Inventories			192
Prepaid expenses and other current assets			62
Goodwill			49,067
Accounts payable - trade			-119
Accrued expenses and other payables			-293
Other noncurrent liabilities			-64
Fair value of net assets acquired			158,366
Other Water Solutions | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		2,146
Inventories		192
Prepaid expenses and other current assets		61
Goodwill		47,750
Accounts payable - trade		-119
Accrued expenses and other payables		-293
Other noncurrent liabilities		-64
Fair value of net assets acquired		158,366
Other Water Solutions | Change
Estimated fair values of the assets acquired and liabilities assumed
Prepaid expenses and other current assets			1
Goodwill			1,317
Other Water Solutions | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			72,000
Other Water Solutions | Customer relationships | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		72,000
Other Water Solutions | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			3,325
Other Water Solutions | Trade names | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		3,325
Other Water Solutions | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			260
Useful life of intangible assets			3 years
Other Water Solutions | Non-compete agreements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		260
Other Water Solutions | Water facility development agreement
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			14,000
Useful life of intangible assets			5 years
Other Water Solutions | Water facility development agreement | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		14,000
Other Water Solutions | Water facility option agreement
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			2,500
Other Water Solutions | Water facility option agreement | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		2,500
Other Water Solutions | Minimum | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets			8 years
Other Water Solutions | Maximum | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Useful life of intangible assets			10 years
Other Water Solutions | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			76
Other Water Solutions | Vehicles | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		90
Other Water Solutions | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-14
Other Water Solutions | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years
Other Water Solutions | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			10 years
Other Water Solutions | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			11,717
Other Water Solutions | Water treatment facilities and equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		14,394
Other Water Solutions | Water treatment facilities and equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-2,677
Other Water Solutions | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			3,278
Other Water Solutions | Buildings and leasehold improvements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		1,906
Other Water Solutions | Buildings and leasehold improvements | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,372
Other Water Solutions | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Other Water Solutions | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			30 years
Other Water Solutions | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			207
Other Water Solutions | Land | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		206
Other Water Solutions | Land | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1
Other Water Solutions | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			12
Other Water Solutions | Other | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		12
Disposal facilities acquired under option and development agreements
Acquisitions
Cash paid, net of cash acquired					3,700
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			124
Inventories			119
Goodwill			15,443
Accounts payable - trade			-232
Other noncurrent liabilities			-50
Fair value of net assets acquired			27,287
Purchase price						21,000
Disposal facilities acquired under option and development agreements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		245
Inventories		197
Goodwill		15,281
Accounts payable - trade		-263
Accrued expenses and other payables		-7
Other noncurrent liabilities		-50
Fair value of net assets acquired		27,287
Disposal facilities acquired under option and development agreements | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-121
Inventories			-78
Goodwill			162
Accounts payable - trade			31
Accrued expenses and other payables			7
Disposal facilities acquired under option and development agreements | Water treatment facilities and equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			10,539
Disposal facilities acquired under option and development agreements | Water treatment facilities and equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		10,540
Disposal facilities acquired under option and development agreements | Water treatment facilities and equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-1
Disposal facilities acquired under option and development agreements | Water treatment facilities and equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Disposal facilities acquired under option and development agreements | Water treatment facilities and equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			30 years
Disposal facilities acquired under option and development agreements | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1,130
Disposal facilities acquired under option and development agreements | Buildings and leasehold improvements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		1,130
Disposal facilities acquired under option and development agreements | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			7 years
Disposal facilities acquired under option and development agreements | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			30 years
Disposal facilities acquired under option and development agreements | Land
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			213
Disposal facilities acquired under option and development agreements | Land | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		213
Disposal facilities acquired under option and development agreements | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			1
Disposal facilities acquired under option and development agreements | Other | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		1
Disposal facilities acquired under option and development agreements | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			3 years
Disposal facilities acquired under option and development agreements | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment			5 years

Acquisitions_Details_71

Acquisitions (Details 7) (USD $)	12 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2013	Mar. 31, 2014	Sep. 30, 2014	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012
	item
Acquisitions
Number of business acquired	2
Cash paid, net of cash acquired	$14,000
Estimated fair values of the assets acquired and liabilities assumed
Goodwill	555,220	1,107,006	1,170,490	167,245	8,568
Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years
Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		25 years
Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment						17,851
Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		40 years	40 years
Crude Oil Logistics
Acquisitions
Number of business acquired		2
Value of common units issued		5,300
Cash paid, net of cash acquired		67,800
Common units issued		175,211
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		1,235	1,221
Inventories		1,021	1,021
Prepaid expenses and other current assets		54	58
Goodwill		37,867	30,730
Accounts payable - trade		-665	-521
Accrued expenses and other payables		-124	-266
Fair value of net assets acquired		73,090	73,090
Crude Oil Logistics | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade		1,235
Inventories		1,021
Prepaid expenses and other current assets		54
Goodwill		37,867
Accounts payable - trade		-665
Accrued expenses and other payables		-124
Fair value of net assets acquired		73,090
Crude Oil Logistics | Change
Estimated fair values of the assets acquired and liabilities assumed
Accounts receivable - trade			-14
Prepaid expenses and other current assets			4
Goodwill			-7,137
Accounts payable - trade			144
Accrued expenses and other payables			-142
Crude Oil Logistics | Customer relationships
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		6,300	13,300
Useful life of intangible assets		3 years	3 years
Crude Oil Logistics | Customer relationships | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		6,300
Crude Oil Logistics | Customer relationships | Change
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets			7,000
Crude Oil Logistics | Non-compete agreements
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		35	35
Useful life of intangible assets		3 years	3 years
Crude Oil Logistics | Non-compete agreements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		35
Crude Oil Logistics | Trade names
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		530	530
Crude Oil Logistics | Trade names | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Intangible assets		530
Crude Oil Logistics | Vehicles
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,977	2,980
Crude Oil Logistics | Vehicles | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		2,977
Crude Oil Logistics | Vehicles | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			3
Crude Oil Logistics | Vehicles | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Crude Oil Logistics | Vehicles | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		10 years	10 years
Crude Oil Logistics | Buildings and leasehold improvements
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		280	58
Crude Oil Logistics | Buildings and leasehold improvements | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		280
Crude Oil Logistics | Buildings and leasehold improvements | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			-222
Crude Oil Logistics | Buildings and leasehold improvements | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years
Crude Oil Logistics | Buildings and leasehold improvements | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Crude Oil Logistics | Crude oil tanks and related equipment
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		3,462	3,822
Crude Oil Logistics | Crude oil tanks and related equipment | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		3,462
Crude Oil Logistics | Crude oil tanks and related equipment | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			360
Crude Oil Logistics | Crude oil tanks and related equipment | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		2 years	2 years
Crude Oil Logistics | Crude oil tanks and related equipment | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		30 years	30 years
Crude Oil Logistics | Barges and towboats
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		20,065	20,065
Useful life of property, plant and equipment		20 years	20 years
Crude Oil Logistics | Barges and towboats | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		20,065
Crude Oil Logistics | Other
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		53	57
Crude Oil Logistics | Other | Estimated
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment		53
Crude Oil Logistics | Other | Change
Estimated fair values of the assets acquired and liabilities assumed
Property, plant and equipment			4
Crude Oil Logistics | Other | Minimum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		3 years	3 years
Crude Oil Logistics | Other | Maximum
Estimated fair values of the assets acquired and liabilities assumed
Useful life of property, plant and equipment		5 years	5 years

Acquisitions_Details_81

Acquisitions (Details 8) (USD $)	12 Months Ended	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2014	Mar. 31, 2014
	item	item	item
Acquisitions
Number of business combination agreements	2
Cash paid	$14,000
Retail propane
Acquisitions
Number of business combination agreements		3	4
Cash paid		6,400
Retail propane and liquids
Acquisitions
Cash paid			21,900
Natural gas liquids terminals
Acquisitions
Number of business combination agreements			4
Number of business combination agreements			4

Property_Plant_and_Equipment_D1

Property, Plant and Equipment (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Property, Plant and Equipment
Property, plant and equipment, gross	$1,586,370,000		$1,586,370,000		$938,910,000	$576,564,000
Less: Accumulated depreciation	-153,057,000		-153,057,000		-109,564,000	-50,127,000
Net property, plant and equipment	1,433,313,000		1,433,313,000		829,346,000	526,437,000
Depreciation expense	28,400,000	13,700,000	46,900,000	27,200,000	59,900,000	39,200,000	10,600,000
Natural gas liquids terminal assets
Property, Plant and Equipment
Property, plant and equipment, gross	127,258,000		127,258,000		75,141,000	63,637,000
Natural gas liquids terminal assets | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Natural gas liquids terminal assets | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Refined products and renewables terminal assets and equipment
Property, Plant and Equipment
Useful life			20 years
Property, plant and equipment, gross	419,411,000		419,411,000
Retail propane equipment
Property, Plant and Equipment
Property, plant and equipment, gross	167,825,000		167,825,000		160,758,000	152,802,000
Retail propane equipment | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Retail propane equipment | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Vehicles and railcars
Property, Plant and Equipment
Property, plant and equipment, gross	172,799,000		172,799,000		152,676,000
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	209,644,000		209,644,000		180,985,000	91,944,000
Water treatment facilities and equipment | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Water treatment facilities and equipment | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Crude oil tanks and related equipment
Property, Plant and Equipment
Property, plant and equipment, gross	145,287,000		145,287,000		106,125,000	22,577,000
Crude oil tanks and related equipment | Minimum
Property, Plant and Equipment
Useful life			2 years		2 years
Crude oil tanks and related equipment | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Barges and towboats
Property, Plant and Equipment
Property, plant and equipment, gross	56,094,000		56,094,000		52,217,000	25,963,000
Barges and towboats | Minimum
Property, Plant and Equipment
Useful life			5 years		5 years
Barges and towboats | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Information technology equipment
Property, Plant and Equipment
Property, plant and equipment, gross	30,519,000		30,519,000		20,768,000	12,169,000
Information technology equipment | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Information technology equipment | Maximum
Property, Plant and Equipment
Useful life			7 years		7 years
Buildings and leasehold improvements
Property, Plant and Equipment
Property, plant and equipment, gross	77,415,000		77,415,000		60,004,000	48,975,000
Buildings and leasehold improvements | Minimum
Property, Plant and Equipment
Useful life			3 years		3 years
Buildings and leasehold improvements | Maximum
Property, Plant and Equipment
Useful life			40 years		40 years
Land
Property, Plant and Equipment
Property, plant and equipment, gross	88,350,000		88,350,000		30,241,000	21,815,000
Tank bottoms
Property, Plant and Equipment
Property, plant and equipment, gross	17,679,000		17,679,000		13,403,000
Volume of property, plant and equipment (in barrels)	185,000		185,000
Other
Property, Plant and Equipment
Property, plant and equipment, gross	16,770,000		16,770,000		6,341,000	16,104,000
Other | Minimum
Property, Plant and Equipment
Useful life			3 years		5 years
Other | Maximum
Property, Plant and Equipment
Useful life			30 years		30 years
Construction in progress
Property, Plant and Equipment
Property, plant and equipment, gross	57,319,000		57,319,000		80,251,000	32,405,000
Vehicles
Property, Plant and Equipment
Property, plant and equipment, gross					$152,676,000	$88,173,000
Vehicles | Minimum
Property, Plant and Equipment
Useful life					3 years
Vehicles | Maximum
Property, Plant and Equipment
Useful life					25 years

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets (Details) (USD $)	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Goodwill
Goodwill at the beginning of the period	$1,107,006	$555,220	$167,245	$8,568
Revisions to acquisition accounting (Note 4)	-21,614
Acquisitions (Note 4)	86,895	551,786	387,975	158,677
Disposal	-1,797
Goodwill at the end of the period	$1,170,490	$1,107,006	$555,220	$167,245

Goodwill_and_Intangible_Assets3

Goodwill and Intangible Assets (Details 2) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011
In Thousands, unless otherwise specified
Goodwill by segment
Goodwill	$1,170,490	$1,107,006	$555,220	$167,245	$8,568
Crude oil logistics
Goodwill by segment
Goodwill	579,845	606,383	246,345
Water solutions
Goodwill by segment
Goodwill	320,106	262,203	109,470
Liquids
Goodwill by segment
Goodwill	91,135	90,135	87,136
Retail propane
Goodwill by segment
Goodwill	114,285	114,285	112,269
Refined products and renewables
Goodwill by segment
Goodwill	$65,119	$34,000

Goodwill_and_Intangible_Assets4

Goodwill and Intangible Assets (Details 3) (USD $)	12 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Sep. 30, 2014	Mar. 31, 2013
Amortizable
Gross Carrying Amount	$809,064	976,952	$454,157
Accumulated Amortization	116,728	166,484	44,155
Non-Amortizable
Gross carrying amount of intangible assets	831,684	1,004,572	485,587
Trade names
Non-Amortizable
Gross Carrying Amount	22,620	27,620
Customer relationships
Amortizable
Gross Carrying Amount	697,405	761,992	405,160
Accumulated Amortization	83,261	119,439	30,959
Useful Lives	9 years
Customer relationships | Minimum
Amortizable
Useful Lives	3 years	3 years
Customer relationships | Maximum
Amortizable
Useful Lives	20 years	20 years
Customer relationships | Weighted average
Amortizable
Useful Lives		9 years
Pipeline capacity rights
Amortizable
Gross Carrying Amount		94,800
Accumulated Amortization		942
Useful Lives	30 years	30 years
Water facility development agreement
Amortizable
Gross Carrying Amount	14,000	14,000
Accumulated Amortization	2,100	3,500
Useful Lives	5 years	5 years
Executory contracts and other agreements
Amortizable
Gross Carrying Amount	23,920	23,920
Accumulated Amortization	13,190	16,367
Executory contracts and other agreements | Minimum
Amortizable
Useful Lives		5 years
Executory contracts and other agreements | Maximum
Amortizable
Useful Lives		10 years
Non-compete agreements
Amortizable
Gross Carrying Amount	14,161	14,412	11,509
Accumulated Amortization	6,388	8,302	2,871
Non-compete agreements | Minimum
Amortizable
Useful Lives	2 years	2 years
Non-compete agreements | Maximum
Amortizable
Useful Lives	7 years	7 years
Trade names
Amortizable
Gross Carrying Amount	15,489	14,539	2,784
Accumulated Amortization	3,081	5,197	326
Non-Amortizable
Gross Carrying Amount	22,620		31,430
Trade names | Minimum
Amortizable
Useful Lives	2 years	2 years
Trade names | Maximum
Amortizable
Useful Lives	10 years	10 years
Debt issuance costs
Amortizable
Gross Carrying Amount	44,089	53,289	19,494
Accumulated Amortization	$8,708	12,737	$2,981
Debt issuance costs | Minimum
Amortizable
Useful Lives	5 years	5 years
Debt issuance costs | Maximum
Amortizable
Useful Lives	10 years	10 years

Goodwill_and_Intangible_Assets5

Goodwill and Intangible Assets (Details 4) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Amortization related to intangible assets
Amortization expense	$25,812	$13,338	$50,754	$24,636	$72,754	$44,086	$6,615
Future amortization expense of intangible assets
2015 (six months)	50,570		50,570
2016	97,432		97,432		83,449
2017	90,795		90,795		76,826
2018	86,818		86,818		72,857
2019	79,587		79,587		66,826
Thereafter	405,266		405,266		303,408
Total	810,468		810,468		692,336
Depreciation and amortization
Amortization related to intangible assets
Amortization expense	21,711	11,324	42,604	20,600	60,855	29,657	4,538
Cost of sales
Amortization related to intangible assets
Amortization expense	1,984	949	4,121	1,574	6,172	5,285	800
Interest expense
Amortization related to intangible assets
Amortization expense	$2,117	$1,065	$4,029	$2,462	$5,727	$3,375	$1,277

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	6 Months Ended	12 Months Ended	0 Months Ended
	Sep. 30, 2014	Mar. 31, 2014	Jul. 09, 2014	Oct. 16, 2013	Sep. 30, 2013	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011	Jun. 19, 2012
Long-Term Debt
Total debt	$2,442,413,000	$1,636,914,000				$749,062,000
Less - current maturities	5,062,000	7,080,000				8,626,000
Long-term debt	2,437,351,000	1,629,834,000				740,436,000
Summary of assets and liabilities
Cash and cash equivalents	11,823,000	10,440,000			5,528,000	11,561,000	7,832,000	16,337,000
Accounts receivable - trade net	1,433,117,000	900,904,000				562,757,000
Accounts receivable - affiliates	41,706,000	7,445,000				22,883,000
Inventories	941,589,000	310,160,000				126,895,000
Prepaid expenses and other current assets	156,818,000	80,350,000				37,891,000
Property, plant and equipment, net	1,433,313,000	829,346,000				526,437,000
Goodwill	1,170,490,000	1,107,006,000				555,220,000	167,245,000	8,568,000
Intangible assets, net	838,088,000	714,956,000				441,432,000
Investments in unconsolidated entities	482,644,000	189,821,000
Other noncurrent assets	42,091,000	16,795,000				6,542,000
Accounts payable - trade	-1,345,024,000	-740,211,000				-536,055,000
Accounts payable - affiliates	-85,307,000	-76,846,000				-6,900,000
Accrued expenses and other payables	-218,482,000	-141,690,000				-85,606,000
Advance payments received from customers	-106,105,000	-29,965,000				-22,372,000
Long-term debt	-2,437,351,000	-1,629,834,000				-740,436,000
Other noncurrent liabilities	-39,518,000	-9,744,000				-2,205,000
BOSTCO
Summary of assets and liabilities
Investments in unconsolidated entities	244,092,000
TLP
Long-Term Debt
Long-term debt	252,000,000
Summary of assets and liabilities
Cash and cash equivalents	726,000
Accounts receivable - trade net	12,252,000
Accounts receivable - affiliates	1,105,000
Inventories	1,613,000
Prepaid expenses and other current assets	1,363,000
Property, plant and equipment, net	504,272,000
Goodwill	29,118,000
Intangible assets, net	38,571,000
Investments in unconsolidated entities	268,410,000
Other noncurrent assets	1,910,000
Accounts payable - trade	-4,009,000
Accounts payable - affiliates	-146,000
Accrued expenses and other payables	-11,625,000
Advance payments received from customers	-141,000
Long-term debt	-252,000,000
Other noncurrent liabilities	-4,247,000
NET ASSETS	587,172,000
TLP | Credit Facility
Long-Term Debt
Total debt	252,000,000
Maximum borrowing capacity	350,000,000
Outstanding cash borrowings	252,000,000
Outstanding letters of credit	0
Consolidated EBITDA	4.75
Maximum borrowing capacity as multiplier of consolidated EBITDA	352,900,000
Additional Permitted JV investments	75,000,000
TLP | Credit Facility | Minimum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.38%
Interest coverage ratio	3
TLP | Credit Facility | Maximum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.50%
Leverage ratio	4.75
Acquisitions that can be made as percentage of consolidated net tangible assets and permitted JV investments	5.00%
Leverage ratio, in the event of issuance of senior unsecured notes	3.75
TLP | Credit Facility | BOSTCO | Maximum
Long-Term Debt
Permitted JV investments	225,000,000
TLP | Credit Facility | Alternate base rate
Long-Term Debt
Variable interest rate base	base rate
TLP | Credit Facility | Alternate base rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	1.00%
TLP | Credit Facility | Alternate base rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	2.00%
TLP | Credit Facility | LIBOR rate
Long-Term Debt
Variable interest rate base	LIBOR
TLP | Credit Facility | LIBOR rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	2.00%
TLP | Credit Facility | LIBOR rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	3.00%
Revolving Credit Facility
Long-Term Debt
Outstanding cash borrowings	1,100,000,000	922,000,000
Actual leverage ratio	3.4	3
Actual interest coverage ratio	4.8	7
Interest rate (as a percent)	1.91%	1.98%
Revolving Credit Facility | Minimum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.38%	0.38%
Interest coverage ratio	2.75	2.75
Revolving Credit Facility | Maximum
Long-Term Debt
Commitment fees charged on unused credit (as a percent)	0.50%	0.50%
Leverage ratio	4.25	4.25
Revolving Credit Facility | Alternate base rate
Long-Term Debt
Variable interest rate base	base rate	base rate
Revolving Credit Facility | Alternate base rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	0.50%	0.50%
Revolving Credit Facility | Alternate base rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	1.50%	1.50%
Revolving Credit Facility | LIBOR rate
Long-Term Debt
Variable interest rate base	LIBOR	LIBOR
Interest rate margin added to variable rate base (as a percent)	1.75%	0.16%
Reference rate (as a percent)	0.16%	1.75%
Fixed interest rate (as a percent)	1.91%
Interest rate (as a percent)		1.91%
Revolving Credit Facility | LIBOR rate | Minimum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	1.50%	1.50%
Revolving Credit Facility | LIBOR rate | Maximum
Long-Term Debt
Interest rate margin added to variable rate base (as a percent)	2.50%	2.50%
Revolving Credit Facility | Expansion Capital Facility
Long-Term Debt
Total debt	137,000,000	532,500,000				441,500,000
Maximum borrowing capacity	858,000,000	785,500,000
Outstanding cash borrowings	137,000,000	532,500,000
Revolving Credit Facility | Expansion Capital Facility | LIBOR rate
Long-Term Debt
Outstanding cash borrowings	137,000,000	532,500,000
Interest rate (as a percent)	0.00%	1.91%
Revolving Credit Facility | Working Capital Facility
Long-Term Debt
Total debt	942,500,000	389,500,000				36,000,000
Maximum borrowing capacity	1,335,000,000	935,500,000
Outstanding cash borrowings	942,500,000	389,500,000
Outstanding letters of credit	209,200,000	270,600,000
Revolving Credit Facility | Working Capital Facility | Alternate base rate
Long-Term Debt
Outstanding cash borrowings		31,500,000
Interest rate (as a percent)		4.00%
Revolving Credit Facility | Working Capital Facility | LIBOR rate
Long-Term Debt
Outstanding cash borrowings	942,500,000	358,000,000
Interest rate (as a percent)	0.00%	1.91%
Revolving Credit Facility | Letters of credit
Long-Term Debt
Reference rate (as a percent)		1.75%
Fixed interest rate (as a percent)	2.00%
5.125% Senior Notes due 2019
Long-Term Debt
Total debt	400,000,000
Fixed interest rate (as a percent)	5.13%		5.13%
Debt issued			400,000,000
Net proceeds after underwriting fees and estimated offering costs			393,500,000
Initial purchase discount			6,000,000
Estimated offering costs			500,000
6.875% Notes due 2021
Long-Term Debt
Total debt	450,000,000	450,000,000
Fixed interest rate (as a percent)	6.88%	6.88%
Debt issued				450,000,000
Liquidated damages amount per month	100,000
Net proceeds after underwriting fees and estimated offering costs				438,400,000
Initial purchase discount				10,100,000
Estimated offering costs				1,500,000
6.650% Notes due 2022
Long-Term Debt
Total debt	250,000,000	250,000,000				250,000,000
Fixed interest rate (as a percent)	6.65%	6.65%							6.65%
Debt issued									250,000,000
Repayments in semi-annual installments	25,000,000	25,000,000
6.650% Notes due 2022 | Minimum
Long-Term Debt
Debt covenant terms, default trigger amount	10,000,000	10,000,000
Percentage of aggregate principal amount held by trustee or holders to declare notes due and payable	51.00%	51.00%
Other long-term debt
Long-Term Debt
Total debt	$10,913,000	$14,914,000
Notes Due 2021
Long-Term Debt
Fixed interest rate (as a percent)				6.88%

LongTerm_Debt_Details_2

Long-Term Debt (Details 2) (USD $)	Sep. 30, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified
Maturities
2015 (six months)	$2,345
2016	255,128	3,614
2017	2,362	2,356
2018	26,459	26,449
2019	1,130,938	972,238
Thereafter	1,025,181	625,176
Total long-term debt	2,442,413	1,636,914
TLP | Credit Facility
Maturities
2016	252,000
Total long-term debt	252,000
Revolving Credit Facility
Maturities
2019	1,079,500	922,000
Total long-term debt	1,079,500	922,000
2019 Notes
Maturities
Thereafter	400,000
Total long-term debt	400,000
2021 Notes
Maturities
Thereafter	450,000
Total long-term debt	450,000
2022 notes
Maturities
2018	25,000	25,000
2019	50,000	50,000
Thereafter	175,000	175,000
Total long-term debt	250,000	250,000
Other long-term debt
Maturities
2015 (six months)	2,345
2016	3,128
2017	2,362
2018	1,459
2019	1,438
Thereafter	181
Total long-term debt	$10,913

Income_Taxes_Details1

Income Taxes (Details) (USD $)	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
Income Taxes
Minimum percentage of qualifying income of non-taxable subsidiaries	90.00%	90.00%
Uncertain tax positions	$0

Commitments_and_Contingencies_4

Commitments and Contingencies (Details ) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Asset retirement obligations
Asset retirement obligations	$2,700,000		$2,700,000		$2,300,000
Future minimum lease payments
2015 (six months)	71,007,000		71,007,000
2016	106,384,000		106,384,000		93,454,000
2017	88,666,000		88,666,000		64,209,000
2018	74,265,000		74,265,000		49,802,000
2019	49,907,000		49,907,000		29,213,000
Thereafter	117,125,000		117,125,000		58,182,000
Total	507,354,000		507,354,000		428,030,000
Rental expense	$29,300,000	$23,600,000	$54,600,000	$45,500,000	$98,300,000	$84,200,000	$5,200,000

Commitments_and_Contingencies_5

Commitments and Contingencies (Details 2) (Pipeline Capacity Agreements, USD $)	Sep. 30, 2014
In Thousands, unless otherwise specified
Pipeline Capacity Agreements
Pipeline Capacity Agreements
2015 (six months)	$41,822
2016	95,050
2017	82,916
2018	62,565
2019	51,278
Thereafter	107,537
Total	$441,168

Commitments_and_Contingencies_6

Commitments and Contingencies (Details 3) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Commodity contracts
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	$42,659	$8,490	($7,106)
Prepaid expenses and other current assets
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	44,400	43,500
Prepaid expenses and other current assets | Commodity contracts
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	81,682	50,704	5,551
Accrued expenses and other payables
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	36,300	34,600
Accrued expenses and other payables | Commodity contracts
Sales and purchase contracts for natural gas liquids and crude oil
Net asset (liability)	-39,023	-42,214	-12,701
Natural gas liquids
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price purchase commitments (in gallons)	88,574,000	31,111,000
Index-price purchase commitments (in gallons)	528,459,000
Fixed-price sale commitments (in gallons/barrels)	278,391,000	63,944,000
Index-price sale commitments (in gallons/barrels)	370,639,000
Fixed-price purchase commitments	102,000	39,117
Index-price purchase commitments	601,719
Fixed-price sale commitments	351,137	77,682
Index-price sale commitments	512,900
Crude oil
Sales and purchase contracts for natural gas liquids and crude oil
Fixed-price sale commitments (in gallons/barrels)	32,000
Index-price sale commitments (in gallons/barrels)	3,920,000
Index-price purchase commitments (in barrels)	4,437,000
Fixed-price purchase commitments		364,557
Index-price purchase commitments	383,153
Fixed-price sale commitments	2,867	324,765
Index-price sale commitments	$337,528

Equity_Details1

Equity (Details) (USD $)	0 Months Ended	6 Months Ended		12 Months Ended			0 Months Ended	1 Months Ended
	17-May-11	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Jun. 23, 2014	Jul. 31, 2014
Partnership equity
General partner, interest (as a percent)	0.10%	0.10%		0.10%	0.10%
Limited partners, interest (as a percent)		99.90%		99.90%	99.90%
Initial Public Offering
Proceeds from sale of common units, net of offering costs		$370,446,000	$415,089,000	$650,155,000	($642,000)	$74,759,000
Common Units
Initial Public Offering
Number of units sold in public offering	4,025,000						8,000,000
Units issued as a result of option exercised by underwriters								767,100
Proceeds from sale of common units, net of offering costs							338,000,000	32,400,000
Underwriting discounts and commissions							12,300,000
Offering costs							$500,000
Subordinated Units
Partnership Equity
Subordinated units, conversion ratio		1		1

Equity_Details_21

Equity (Details 2) (USD $)

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

Jan. 23, 2014

Oct. 23, 2013

Jul. 25, 2013

Apr. 25, 2013

Jan. 24, 2013

Oct. 17, 2012

Jul. 24, 2012

Apr. 18, 2012

Jan. 24, 2012

Oct. 21, 2011

Jul. 25, 2011

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

Apr. 24, 2014

Oct. 31, 2014

Distributions to Owners

Third level cash distribution percentage to general partner

0.10%

0.10%

Distributions

Total distributions

$61,500,000

Amount per unit (in dollars per unit)

$0.53

$0.51

$0.49

$0.48

$0.46

$0.45

$0.41

$0.36

$0.35

$0.34

$0.17

TLP

Distributions

Distribution declared per unit (in dollars per unit)

0.665

Amount of distribution declared

0

Amount per unit (in dollars per unit)

$0.67

Amount Paid to Limited Partner

8,700,000

Subsequent event

Distributions

Distribution declared per unit (in dollars per unit)

$0.61

Amount of distribution declared

65,000,000

Amount per unit (in dollars per unit)

$0.55

Subsequent event | TLP

Distributions

Distribution declared per unit (in dollars per unit)

$0.67

Amount of distribution declared

8,700,000

Minimum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.3375

0.3375

Minimum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.4

First target distribution | Minimum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.3375

0.3375

First target distribution | Minimum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.4

First target distribution | Maximum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.388125

0.388125

First target distribution | Maximum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.44

Second target distribution | Minimum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.388125

0.388125

Second target distribution | Minimum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.44

Second target distribution | Maximum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.421875

0.421875

Second target distribution | Maximum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.5

Third target distribution | Minimum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.421875

0.421875

Third target distribution | Minimum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.5

Third target distribution | Maximum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.50625

0.50625

Third target distribution | Maximum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.6

Thereafter | Minimum

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.50625

0.50625

Thereafter | Minimum | TLP

Distributions

Total Quarterly Distribution per Unit (in dollars per unit)

0.6

Limited Partners

Distributions

Marginal Percentage Interest In Distributions

99.90%

99.90%

Distribution declared per unit (in dollars per unit)

0.5888

Amount Paid to Limited Partner

42,150,000

35,908,000

31,725,000

25,605,000

24,245,000

22,846,000

13,574,000

9,165,000

7,735,000

4,990,000

2,467,000

Limited Partners | TLP

Distributions

Marginal Percentage Interest In Distributions

98.00%

Limited Partners | Subsequent event

Distributions

Amount Paid to Limited Partner

43,737,000

Limited Partners | Common Units

Distributions

Total distributions (in dollars per unit)

$0.59

0.5888

Limited Partners | Subordinated Units

Distributions

Total distributions (in dollars per unit)

$0.59

0.5888

Limited Partners | First target distribution

Distributions

Marginal Percentage Interest In Distributions

99.90%

99.90%

Limited Partners | First target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

98.00%

Limited Partners | Second target distribution

Distributions

Marginal Percentage Interest In Distributions

86.90%

86.90%

Limited Partners | Second target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

85.00%

Limited Partners | Third target distribution

Distributions

Marginal Percentage Interest In Distributions

76.90%

76.90%

Limited Partners | Third target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

75.00%

Limited Partners | Thereafter

Distributions

Marginal Percentage Interest In Distributions

51.90%

51.90%

Limited Partners | Thereafter | TLP

Distributions

Marginal Percentage Interest In Distributions

50.00%

General Partner

Distributions

Marginal Percentage Interest In Distributions

0.10%

0.10%

Incentive distribution to general partner

9,500,000

Distribution declared per unit (in dollars per unit)

0.5888

General Partner | TLP

Distributions

Marginal Percentage Interest In Distributions

2.00%

General Partner | Notional units

Distributions

Total distributions (in dollars per unit)

$0.59

0.5888

General Partner | First target distribution

Distributions

Marginal Percentage Interest In Distributions

0.10%

0.10%

General Partner | First target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

2.00%

General Partner | Second target distribution

Distributions

Marginal Percentage Interest In Distributions

13.10%

13.10%

General Partner | Second target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

15.00%

General Partner | Third target distribution

Distributions

Marginal Percentage Interest In Distributions

23.10%

23.10%

General Partner | Third target distribution | TLP

Distributions

Marginal Percentage Interest In Distributions

25.00%

General Partner | Thereafter

Distributions

Marginal Percentage Interest In Distributions

48.10%

48.10%

General Partner | Thereafter | TLP

Distributions

Marginal Percentage Interest In Distributions

50.00%

Equity_Details_31

Equity (Details 3) (USD $)	6 Months Ended	12 Months Ended		3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2013	17-May-11
Equity-Based Incentive Compensation
Amount of withholding taxes paid on behalf of recipient	$9,901	$3,750	$1,468
Rollforward of the liability related to equity-based compensation
Balance at the beginning of the period	10,012	5,043				5,043
Expense recorded	21,659	17,804	10,138
Value of units vested and issued	-18,763	-9,085	-3,627
Taxes paid on behalf of participants	-9,901	-3,750	-1,468
Balance at the end of the period	3,007	10,012	5,043	3,007
Maximum number of shares that may be issued as a percentage of outstanding common units	10.00%	10.00%
Incremental amount that the maximum units deliverable may automatically increase under the plan, expressed as a percentage of issued and outstanding common units	10.00%	10.00%
Common Units
Equity-Based Incentive Compensation
Closing price (in dollars per share)							$21
Estimated
Equity-Based Incentive Compensation
Estimate of forfeiture of unvested awards	80,000
Restricted units
Equity-Based Incentive Compensation
Distributions on restricted units during the vesting period	0	0
Unvested restricted units at the beginning of the period (in shares)	1,311,100	1,444,900				1,444,900
Units granted (in shares)	333,903	494,000	1,684,400
Units vested and issued (in shares)	-438,009	-296,269	-156,802
Units withheld for employee taxes (in shares)	-231,194	-122,531	-61,698
Units forfeited (in shares)	-117,000	-209,000	-21,000
Unvested restricted units at the end of the period (in shares)	858,800	1,311,100	1,444,900	858,800
Number of awards vested	858,800	1,311,100
Estimate of forfeiture of unvested awards		95,000
Closing price (in dollars per share)	$39.37	$37.53		$39.37
Estimated stock-based compensation expense
2015 (six months)	6,343
2016	11,516	11,279
2017	7,262	7,429
2018	2,237	2,310
2019	249	229
Total	27,607	35,640
Rollforward of the liability related to equity-based compensation
Expense recorded	$21,700			$13,800	$3,200	$10,300
Weighted-average grant date fair value of the awards (in dollars per unit)	$35.16	$33.78		$35.16
Number of units available for issuance under the Long-Term Incentive Plan	7,100,000	6,200,000		7,100,000
Restricted units | July 1, 2015
Equity-Based Incentive Compensation
Number of awards vested	334,800	341,300
Restricted units | July 1, 2016
Equity-Based Incentive Compensation
Number of awards vested	314,000	322,500
Restricted units | July 1, 2017
Equity-Based Incentive Compensation
Number of awards vested	178,500	192,500
Restricted units | July 1, 2018
Equity-Based Incentive Compensation
Number of awards vested	31,500	30,500

Fair_Value_of_Financial_Instru7

Fair Value of Financial Instruments (Details) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Mar. 31, 2013
In Thousands, unless otherwise specified
Prepaid expenses and other current assets
Derivative assets (liabilities)
Net asset	$44,400	$43,500
Accrued expenses and other payables
Derivative assets (liabilities)
Net asset	36,300	34,600
Commodity derivatives
Derivative assets (liabilities)
Net asset	42,659	8,490	-7,106
Commodity derivatives | Prepaid expenses and other current assets
Derivative assets (liabilities)
Net asset	81,682	50,704	5,551
Commodity derivatives | Accrued expenses and other payables
Derivative assets (liabilities)
Net asset	-39,023	-42,214	-12,701
Recurring | Commodity derivatives
Assets:
Derivative Assets	100,021	54,595	10,858
Liabilities:
Derivative Liabilities	-43,658	-46,561	-16,604
Netting of counterparty contracts, assets	-4,635	-4,347	-3,503
Netting of counterparty contracts, liabilities	4,635	4,347	3,503
Cash collateral held, assets	-13,704	456	-1,760
Commodity derivatives reported on condensed consolidated balance sheet, assets	81,682	50,704	5,595
Commodity derivatives reported on condensed consolidated balance sheet, liabilities	-39,023	-42,214	-12,701
Recurring | Level 1 | Commodity derivatives
Assets:
Derivative Assets	48,632	4,990	947
Liabilities:
Derivative Liabilities	-5,378	-3,258	-3,324
Recurring | Level 2 | Commodity derivatives
Assets:
Derivative Assets	51,389	49,605	9,911
Liabilities:
Derivative Liabilities	($38,280)	($43,303)	($13,280)

Fair_Value_of_Financial_Instru8

Fair Value of Financial Instruments (Details 2) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Derivative contract information
Fair Value of Net Assets (Liabilities)	$56,363		$56,363		$8,034	($5,746)
Net cash collateral held	-13,704		-13,704		456	-1,360
Net fair value of commodity derivatives on condensed consolidated balance sheet	42,659		42,659		8,490	-7,106
Cross-commodity
Derivative contract information
Total Notional Units (Barrels)	-12,000		-12,000		140,000	430,000
Fair Value of Net Assets (Liabilities)	-1,283		-1,283		-1,876	-10,208
Crude oil fixed-price
Derivative contract information
Total Notional Units (Barrels)	-1,638,000		-1,638,000		-1,600,000	-144,000
Fair Value of Net Assets (Liabilities)	9,380		9,380		-2,796	1,033
Crude oil index
Derivative contract information
Total Notional Units (Barrels)	2,195,000		2,195,000		3,598,000	-91,000
Fair Value of Net Assets (Liabilities)	4,397		4,397		6,099	153
Propane fixed-price
Derivative contract information
Total Notional Units (Barrels)	1,238,000		1,238,000		60,000	-282,000
Fair Value of Net Assets (Liabilities)	53		53		1,753	3,197
Refined products fixed-price
Derivative contract information
Total Notional Units (Barrels)	-4,475,000		-4,475,000		732,000
Fair Value of Net Assets (Liabilities)	38,712		38,712		560
Renewable products
Derivative contract information
Total Notional Units (Barrels)	-14,000		-14,000		106,000
Fair Value of Net Assets (Liabilities)	5,104		5,104		4,084
Other
Derivative contract information
Total Notional Units (Barrels)						8,000
Fair Value of Net Assets (Liabilities)					210	79
Commodity contracts
Derivative contract information
Net gains (losses) on derivatives	$55,981	($10,672)	$38,496	($17,881)	($43,655)	($4,381)	$5,676

Fair_Value_of_Financial_Instru9

Fair Value of Financial Instruments (Details 3) (USD $)	6 Months Ended	12 Months Ended
	Sep. 30, 2014	Mar. 31, 2014
TLP | Credit Facility
Interest Rate Risk
Outstanding debt	$252,000,000
Revolving Credit Facility
Interest Rate Risk
Outstanding debt	1,100,000,000	922,000,000
Interest rate (as a percent)	1.91%	1.98%
Interest Rate Risk | TLP | Credit Facility
Interest Rate Risk
Outstanding debt	252,000,000
Interest rate (as a percent)	2.66%
Change in interest rate that would result in an increase or decrease of annual interest expense (as a percent)	0.13%
Increase or decrease in annual interest expense	300,000
Interest Rate Risk | Variable Rate Debt
Interest Rate Risk
Change in interest rate that would result in an increase or decrease of annual interest expense (as a percent)	0.13%	0.13%
Increase or decrease in annual interest expense	$1,300,000	$1,200,000

Recovered_Sheet10

Fair Value of Financial Instruments (Details 4) (USD $)	Sep. 30, 2014
In Thousands, unless otherwise specified
5.125% Senior Notes due 2019
Fair Value of Fixed - Rate Notes
Fair value of Fixed - Rate Notes	$390,000
6.875% Notes due 2021
Fair Value of Fixed - Rate Notes
Fair value of Fixed - Rate Notes	475,000
6.650% Notes due 2022
Fair Value of Fixed - Rate Notes
Fair value of Fixed - Rate Notes	$275,000

Segments_Details1

Segments (Details) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Segment information
Revenues	$5,380,526	$3,975,935	$2,743,445	$1,593,937	$1,385,957	$1,617,613	$1,338,208	$1,135,510	$326,436	$9,029,140	$2,979,894	$9,699,274	$4,417,767	$1,310,473
Depreciation and amortization	50,099			25,061						89,474	47,785	120,754	68,853	15,111
Operating Income	7,770			9,945						-12,785	2,603	106,565	87,307	15,030
Additions to property, plant and equipment	605,642			111,781						660,509	146,298	390,989	326,896	200,457
Total assets	6,551,679	4,167,223				2,291,618				6,551,679		4,167,223	2,291,618
Long-lived assets, net	3,441,891	2,651,308				1,523,089				3,441,891		2,651,308	1,523,089
Crude oil logistics
Segment information
Depreciation and amortization	9,240			3,330						18,971	8,014	22,111	9,176
Operating Income	38			5,884						1,501	12,493	678	34,236
Additions to property, plant and equipment	39,464			31,336						81,413	35,462	204,642	89,860
Total assets	2,079,380	1,723,812				801,351				2,079,380		1,723,812	801,351
Long-lived assets, net	996,615	980,978				357,230				996,615		980,978	357,230
Water solutions
Segment information
Depreciation and amortization	17,573			11,438						34,665	18,794
Operating Income	14,792			2,913						13,885	5,956
Additions to property, plant and equipment	40,610			62,473						48,072	70,182
Total assets	964,336	875,714								964,336		875,714
Long-lived assets, net	910,467	848,479								910,467		848,479
Liquids
Segment information
Depreciation and amortization	3,384			2,672						6,585	5,376	11,018	11,085	3,661
Operating Income	10,929			14,605						10,016	12,490	71,888	30,336	9,735
Additions to property, plant and equipment	1,911			13,209						3,070	28,316	52,560	15,129	50,276
Total assets	756,133	577,795				474,141				756,133		577,795	474,141
Long-lived assets, net	271,567	274,846				238,192				271,567		274,846	238,192
Retail propane
Segment information
Number of operating divisions										2		2
Depreciation and amortization	7,684			6,871						15,255	14,111	28,878	25,496	11,450
Operating Income	-3,062			-4,520						-4,648	-6,024	61,285	46,869	9,616
Additions to property, plant and equipment	9,567			4,546						12,441	11,492	24,430	66,933	150,181
Total assets	506,958	541,832				513,301				506,958		541,832	513,301
Long-lived assets, net	436,621	438,324				441,762				436,621		438,324	441,762
Refined products and renewables
Segment information
Depreciation and amortization	11,917									12,761
Operating Income	8,822									7,567
Additions to property, plant and equipment	512,281									512,281
Total assets	2,183,674	303,230								2,183,674		303,230
Long-lived assets, net	772,916	60,720								772,916		60,720
Corporate and other
Segment information
Depreciation and amortization	301			750						1,237	1,490	3,017	2,173
Operating Income	-23,749			-8,937						-41,106	-22,312	-44,117	-32,710	-4,321
Additions to property, plant and equipment	1,809			217						3,262	846	7,242	17,858
Total assets	61,198	144,840				36,413				61,198		144,840	36,413
Long-lived assets, net	53,705	47,961				31,996				53,705		47,961	31,996
Operating segment | Crude oil logistics | Crude oil sales
Segment information
Revenues	2,108,117			1,013,061						4,035,061	1,941,595	4,559,923	2,322,706
Operating segment | Crude oil logistics | Crude oil transportation and other
Segment information
Revenues	13,082			9,794						25,196	19,729	36,469	16,442
Operating segment | Water solutions | Water treatment and disposal
Segment information
Revenues	47,572			28,823						89,288	47,511
Operating segment | Water solutions | Water transportation
Segment information
Revenues	5,147			5,367						10,745	7,192
Operating segment | Liquids | Propane sales
Segment information
Revenues	240,433			191,437						462,879	315,274	1,632,948	841,448	923,022
Operating segment | Liquids | Other product sales
Segment information
Revenues	306,625			308,606						594,984	558,459	1,231,965	858,276	251,627
Operating segment | Liquids | Other revenues
Segment information
Revenues	6,814			9,250						12,530	18,114	31,062	33,954	2,462
Operating segment | Retail propane | Propane sales
Segment information
Revenues	48,552			40,651						100,578	87,342	388,225	288,410	175,417
Operating segment | Retail propane | Distillate sales
Segment information
Revenues	11,530			10,562						30,255	28,431	127,672	106,192	6,547
Operating segment | Retail propane | Other revenues
Segment information
Revenues	8,276			8,198						15,457	15,898	35,918	35,856	17,370
Operating segment | Refined products and renewables | Refined products sales
Segment information
Revenues	2,489,795									3,476,018
Operating segment | Refined products and renewables | Renewables sales
Segment information
Revenues	117,425									248,699
Operating segment | Corporate and other
Segment information
Revenues	1,333			1,485						2,794	2,959	437,713	4,233
Elimination of intersegment sales
Segment information
Revenues	($24,175)			($33,297)						($75,314)	($62,610)	($283,397)	($151,977)	($65,972)

Transactions_with_Affiliates_D1

Transactions with Affiliates (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Transactions with Affiliates
Receivables from affiliates	$41,706,000		$41,706,000		$7,445,000	$22,883,000
Payables to related parties	85,307,000		85,307,000		76,846,000	6,900,000
SemGroup
Transactions with Affiliates
Sales to related party	43,427,000	3,780,000	117,233,000	3,780,000	306,780,000	32,431,000	29,200,000
Purchase from related parties	45,730,000	28,377,000	118,997,000	47,916,000	445,951,000	60,425,000	23,800,000
Receivables from affiliates	39,331,000		39,331,000		7,303,000
Payables to related parties	44,015,000		44,015,000		27,738,000	4,601,000
Equity method investee
Transactions with Affiliates
Sales to related party	9,131,000		9,131,000
Purchase from related parties	34,689,000		70,965,000
Receivables from affiliates	670,000		670,000
Payables to related parties	39,549,000		39,549,000		48,454,000
Entities affiliated with management
Transactions with Affiliates
Increase in property, plant and equipment			5,800,000		8,200,000
Sales to related party	1,706,000	58,769,000	1,854,000	109,872,000	110,824,000	16,828,000
Purchase from related parties	3,845,000	48,522,000	6,984,000	56,346,000	120,038,000	60,942,000
Receivables from affiliates	1,705,000		1,705,000		142,000	22,883,000
Payables to related parties	$1,743,000		$1,743,000		$654,000	$2,299,000

Condensed_Consolidating_Guaran8

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details) (Guarantor Subsidiaries, USD $)	Sep. 30, 2014
Guarantor Subsidiaries
Condensed consolidating financial information
Restricted net assets	$0

Condensed_Consolidating_Guaran9

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 2) (USD $)	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$11,823	$10,440	$5,528	$11,561	$7,832	$16,337
Accounts receivable - trade, net of allowance for doubtful accounts	1,433,117	900,904		562,757
Accounts receivable - affiliates	41,706	7,445		22,883
Inventories	941,589	310,160		126,895
Prepaid expenses and other current assets	156,818	80,350		37,891
Total current assets	2,585,053	1,309,299		761,987
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	1,433,313	829,346		526,437
GOODWILL	1,170,490	1,107,006		555,220	167,245	8,568
INTANGIBLE ASSETS, net of accumulated amortization	838,088	714,956		441,432
INVESTMENTS IN UNCONSOLIDATED ENTITIES	482,644	189,821
OTHER NONCURRENT ASSETS	42,091	16,795		6,542
Total assets	6,551,679	4,167,223		2,291,618
CURRENT LIABILITIES:
Accounts payable - trade	1,345,024	740,211		536,055
Accounts payable - affiliates	85,307	76,846		6,900
Accrued expenses and other payables	218,482	141,690		85,606
Advance payments received from customers	106,105	29,965		22,372
Current maturities of long-term debt	5,062	7,080		8,626
Total current liabilities	1,759,980	995,792		659,559
LONG-TERM DEBT, net of current maturities	2,437,351	1,629,834		740,436
OTHER NONCURRENT LIABILITIES	39,518	9,744		2,205
EQUITY
Partners' equity (deficit)	1,746,133	1,526,815		883,654
Accumulated other comprehensive loss	-73	-236		24
Noncontrolling interests	568,770	5,274		5,740
Total equity	2,314,830	1,531,853		889,418	405,329	47,353
Total liabilities and equity	6,551,679	4,167,223		2,291,618
Reportable Entity | NGL Energy Partners LP (Parent)
CURRENT ASSETS:
Cash and cash equivalents	2,841	1,181	1,346		41	41
Total current assets	2,841	1,181
INTANGIBLE ASSETS, net of accumulated amortization	1,307	1,169		717
NET INTERCOMPANY RECEIVABLES (PAYABLES)	248,893	327,281		237,736
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	1,743,573	1,447,502		895,779
Total assets	1,996,614	1,777,133		1,134,232
CURRENT LIABILITIES:
Accrued expenses and other payables	554	554		554
Total current liabilities	554	554		554
LONG-TERM DEBT, net of current maturities	250,000	250,000		250,000
EQUITY
Partners' equity (deficit)	1,746,060	1,526,579		883,678
Total equity	1,746,060	1,526,579		883,678
Total liabilities and equity	1,996,614	1,777,133		1,134,232
Reportable Entity | NGL Energy Finance Corp
CURRENT ASSETS:
INTANGIBLE ASSETS, net of accumulated amortization	17,619	11,552
NET INTERCOMPANY RECEIVABLES (PAYABLES)	849,526	437,714
Total assets	867,145	449,266
CURRENT LIABILITIES:
Accrued expenses and other payables	19,021	14,266
Total current liabilities	19,021	14,266
LONG-TERM DEBT, net of current maturities	850,000	450,000
EQUITY
Partners' equity (deficit)	-1,876	-15,000
Total equity	-1,876	-15,000
Total liabilities and equity	867,145	449,266
Reportable Entity | Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	7,823	8,728	3,904	11,206	7,594	16,174
Accounts receivable - trade, net of allowance for doubtful accounts	1,419,442	887,789		561,560
Accounts receivable - affiliates	41,035	7,445		22,883
Inventories	937,814	306,434		126,024
Prepaid expenses and other current assets	155,332	80,294		37,784
Total current assets	2,561,446	1,290,690		759,457
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	863,694	764,014		497,743
GOODWILL	1,139,374	1,105,008		553,222
INTANGIBLE ASSETS, net of accumulated amortization	778,960	700,603		439,365
INVESTMENTS IN UNCONSOLIDATED ENTITIES	214,234	189,821
NET INTERCOMPANY RECEIVABLES (PAYABLES)	-1,026,605	-720,737		-233,294
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	10,470	17,673		20,371
OTHER NONCURRENT ASSETS	40,035	16,674		6,542
Total assets	4,581,608	3,363,746		2,043,406
CURRENT LIABILITIES:
Accounts payable - trade	1,333,780	726,252		534,164
Accounts payable - affiliates	85,237	73,703		6,900
Accrued expenses and other payables	186,226	124,923		83,001
Advance payments received from customers	105,597	29,891		22,364
Current maturities of long-term debt	5,004	7,058		8,610
Total current liabilities	1,715,844	961,827		655,039
LONG-TERM DEBT, net of current maturities	1,085,155	929,754		490,433
OTHER NONCURRENT LIABILITIES	35,160	9,663		2,155
EQUITY
Partners' equity (deficit)	1,745,450	1,462,691		895,779
Accumulated other comprehensive loss	-1	-189
Total equity	1,745,449	1,462,502		895,779
Total liabilities and equity	4,581,608	3,363,746		2,043,406
Reportable Entity | Non-Guarantor Subsidiaries
CURRENT ASSETS:
Cash and cash equivalents	1,159	531	278	355	197	122
Accounts receivable - trade, net of allowance for doubtful accounts	13,675	13,115		1,197
Accounts receivable - affiliates	671
Inventories	3,775	3,726		871
Prepaid expenses and other current assets	1,486	56		107
Total current assets	20,766	17,428		2,530
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation	569,619	65,332		28,694
GOODWILL	31,116	1,998		1,998
INTANGIBLE ASSETS, net of accumulated amortization	40,202	1,632		1,350
INVESTMENTS IN UNCONSOLIDATED ENTITIES	268,410
NET INTERCOMPANY RECEIVABLES (PAYABLES)	-71,814	-44,258		-4,442
OTHER NONCURRENT ASSETS	2,056	121
Total assets	860,355	42,253		30,130
CURRENT LIABILITIES:
Accounts payable - trade	11,244	13,959		1,891
Accounts payable - affiliates	70	3,143
Accrued expenses and other payables	12,681	1,947		2,051
Advance payments received from customers	508	74		8
Current maturities of long-term debt	58	22		16
Total current liabilities	24,561	19,145		3,966
LONG-TERM DEBT, net of current maturities	252,196	80		3
OTHER NONCURRENT LIABILITIES	4,358	81		50
EQUITY
Partners' equity (deficit)	579,312	22,994		26,087
Accumulated other comprehensive loss	-72	-47		24
Total equity	579,240	22,947		26,111
Total liabilities and equity	860,355	42,253		30,130
Consolidating Adjustments
CURRENT ASSETS:
INVESTMENTS IN CONSOLIDATED SUBSIDIARIES	-1,754,043	-1,465,175		-916,150
Total assets	-1,754,043	-1,465,175		-916,150
EQUITY
Partners' equity (deficit)	-2,322,813	-1,470,449		-921,890
Noncontrolling interests	568,770	5,274		5,740
Total equity	-1,754,043	-1,465,175		-916,150
Total liabilities and equity	($1,754,043)	($1,465,175)		($916,150)

Recovered_Sheet11

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 3) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Condensed Consolidating Statement of Operations
REVENUES	$5,380,526	$3,975,935	$2,743,445	$1,593,937	$1,385,957	$1,617,613	$1,338,208	$1,135,510	$326,436	$9,029,140	$2,979,894	$9,699,274	$4,417,767	$1,310,473
COST OF SALES	5,179,465	3,764,744	2,576,029	1,488,850	1,303,076	1,481,890	1,204,545	1,053,690	298,985	8,713,518	2,791,926	9,132,699	4,039,110	1,217,023
OPERATING COSTS AND EXPENSES:
Operating	101,553			55,769						169,421	104,814	259,396	169,799	47,300
General and administrative	41,639			14,312						69,512	32,766	79,860	52,698	16,009
Depreciation and amortization	50,099			25,061						89,474	47,785	120,754	68,853	15,111
Operating Income (Loss)	7,770			9,945						-12,785	2,603	106,565	87,307	15,030
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	3,697									6,262		1,898
Interest expense	-28,651			-11,060						-49,145	-21,682	-58,854	-32,994	-7,620
Other, net	-617			419						-1,008	469	86	1,521	1,055
Loss before Income Taxes	-17,801			-696						-56,676	-18,610	49,695	50,065	8,465
INCOME TAX (PROVISION) BENEFIT	1,922			-236						887	170	-937	-1,875	-601
Net Loss	-15,879	43,146	24,052	-932	-17,508	22,341	40,477	10,082	-24,710	-55,789	-18,440	48,758	48,190	7,864
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056			-2,451						-20,437	-4,139	-14,148	-2,917	-8
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-3,345			-9						-3,410	-134	-1,103	-250	12
NET LOSS ALLOCATED TO LIMITED PARTNERS	-30,280			-3,392						-79,636	-22,713	33,507	45,023	7,868
Reportable Entity | NGL Energy Partners LP (Parent)
OTHER INCOME (EXPENSE):
Interest expense	-4,067			-4,179						-8,313	-8,368	-16,818	-13,041
Loss before Income Taxes	-4,067			-4,179						-8,313	-8,368	-16,818	-13,041
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	-15,157			3,238						-50,886	-10,206	64,473	60,981	7,876
Net Loss	-19,224			-941						-59,199	-18,574	47,655	47,940	7,876
NET LOSS ALLOCATED TO LIMITED PARTNERS	-19,224			-941						-59,199	-18,574	47,655	47,940	7,876
Reportable Entity | NGL Energy Finance Corp
OTHER INCOME (EXPENSE):
Interest expense	-13,134									-21,280		-15,000
Loss before Income Taxes	-13,134									-21,280		-15,000
Net Loss	-13,134									-21,280		-15,000
NET LOSS ALLOCATED TO LIMITED PARTNERS	-13,134									-21,280		-15,000
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	5,325,186			1,546,226						8,952,772	2,914,531	9,560,124	4,409,198	1,310,473
COST OF SALES	5,161,935			1,445,442						8,676,881	2,735,890	9,011,011	4,038,251	1,217,248
OPERATING COSTS AND EXPENSES:
Operating	84,300			52,979						150,919	99,710	253,214	164,944	47,162
General and administrative	36,360			14,089						64,124	32,297	77,756	52,461	15,823
Depreciation and amortization	38,999			23,970						77,545	46,000	117,573	66,916	14,964
Operating Income (Loss)	3,592			9,746						-16,697	634	100,570	86,626	15,276
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	2,310									4,875		1,898
Interest expense	-9,956			-6,880						-18,058	-13,309	-27,031	-19,951	-7,619
Other, net	-524			528						-1,056	627	202	1,666	1,100
Loss before Income Taxes	-4,578			3,394						-30,936	-12,048	75,639	62,572	8,757
INCOME TAX (PROVISION) BENEFIT	1,951			-236						993	170	-937	-1,875	-601
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	604			80						337	1,672	4,771	284	-280
Net Loss	-2,023			3,238						-29,606	-10,206	79,473	60,981	7,876
NET LOSS ALLOCATED TO LIMITED PARTNERS	-2,023			3,238						-29,606	-10,206	79,473	60,981	7,876
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statement of Operations
REVENUES	55,364			47,735						76,421	65,421	139,519	8,878	225
COST OF SALES	17,554			43,432						36,690	56,094	122,057	1,168
OPERATING COSTS AND EXPENSES:
Operating	17,253			2,790						18,502	5,104	6,182	4,855	138
General and administrative	5,279			223						5,388	469	2,104	237	186
Depreciation and amortization	11,100			1,091						11,929	1,785	3,181	1,937	147
Operating Income (Loss)	4,178			199						3,912	1,969	5,995	681	-246
OTHER INCOME (EXPENSE):
Earnings of unconsolidated entities	1,387									1,387
Interest expense	-1,506			-13						-1,517	-28	-51	-48	-46
Other, net	-81			-97						71	-135	-70	-99
Loss before Income Taxes	3,978			89						3,853	1,806	5,874	534	-292
INCOME TAX (PROVISION) BENEFIT	-29									-106
Net Loss	3,949			89						3,747	1,806	5,874	534	-292
NET LOSS ALLOCATED TO LIMITED PARTNERS	3,949			89						3,747	1,806	5,874	534	-292
Consolidating Adjustments
Condensed Consolidating Statement of Operations
REVENUES	-24			-24						-53	-58	-369	-309	-225
COST OF SALES	-24			-24						-53	-58	-369	-309	-225
OTHER INCOME (EXPENSE):
Interest expense	12			12						23	23	46	46	45
Other, net	-12			-12						-23	-23	-46	-46	-45
EQUITY IN NET INCOME (LOSS) OF CONSOLIDATED SUBSIDIARIES	14,553			-3,318						50,549	8,534	-69,244	-61,265	-7,596
Net Loss	14,553			-3,318						50,549	8,534	-69,244	-61,265	-7,596
LESS: NET INCOME ALLOCATED TO GENERAL PARTNER	-11,056			-2,451						-20,437	-4,139	-14,148	-2,917	-8
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	-3,345			-9						-3,410	-134	-1,103	-250	12
NET LOSS ALLOCATED TO LIMITED PARTNERS	$152			($5,778)						$26,702	$4,261	($84,495)	($64,432)	($7,592)

Recovered_Sheet12

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 4) (USD $)	3 Months Ended									6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	($15,879)	$43,146	$24,052	($932)	($17,508)	$22,341	$40,477	$10,082	($24,710)	($55,789)	($18,440)	$48,758	$48,190	$7,864
Other comprehensive income (loss)	-22			-5						163	-30	-260	-7	-25
Comprehensive loss	-15,901			-937						-55,626	-18,470	48,498	48,183	7,839
Reportable Entity | NGL Energy Partners LP (Parent)
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	-19,224			-941						-59,199	-18,574	47,655	47,940	7,876
Comprehensive loss	-19,224			-941						-59,199	-18,574	47,655	47,940	7,876
Reportable Entity | NGL Energy Finance Corp
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	-13,134									-21,280		-15,000
Comprehensive loss	-13,134									-21,280		-15,000
Reportable Entity | Guarantor Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	-2,023			3,238						-29,606	-10,206	79,473	60,981	7,876
Other comprehensive income (loss)	4									189		-189
Comprehensive loss	-2,019			3,238						-29,417	-10,206	79,284	60,981	7,876
Reportable Entity | Non-Guarantor Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	3,949			89						3,747	1,806	5,874	534	-292
Other comprehensive income (loss)	-26			-5						-26	-30	-71	-7	-25
Comprehensive loss	3,923			84						3,721	1,776	5,803	527	-317
Consolidating Adjustments
Condensed Consolidating Statements of Comprehensive Income (Loss)
Net income (loss)	14,553			-3,318						50,549	8,534	-69,244	-61,265	-7,596
Comprehensive loss	$14,553			($3,318)						$50,549	$8,534	($69,244)	($61,265)	($7,596)

Recovered_Sheet13

Condensed Consolidating Guarantor and Non-Guarantor Financial Information (Details 5) (USD $)	6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2012
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	($61,635)	($48,744)	$85,236	$132,634	$90,329
INVESTING ACTIVITIES:
Purchases of long-lived assets	-82,851	-67,399	-165,148	-72,475	-7,544
Acquisitions of businesses, including acquired working capital, net of cash acquired	-658,764	-392,605	-1,268,810	-490,805	-297,401
Cash flows from commodity derivatives	4,327	-19,074
Proceeds from sales of assets	8,741	2,224	24,660	5,080	1,238
Investments in unconsolidated entities	-26,390		-11,515
Distributions of capital from unconsolidated entities	4,649
Net cash used in investing activities	-750,288	-476,854	-1,455,373	-546,621	-296,897
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,979,500	1,061,500	2,545,500	1,227,975	478,900
Payments on revolving credit facilities	-1,804,000	-893,000	-2,101,000	-964,475	-329,900
Issuance of notes	400,000		450,000	250,000
Proceeds from borrowings on other long-term debt		880	880	653
Payments on other long-term debt	-4,175	-4,507	-8,819	-4,837	-1,278
Debt issuance costs	-9,198	-2,218	-24,595	-20,189	-2,380
Contributions	395	2,444	2,825	913	440
Distributions to owners	-111,008	-60,623
Distributions to noncontrolling interest partners	-8,654
Proceeds from sale of common units, net of offering costs	370,446	415,089	650,155	-642	74,759
Net cash provided by financing activities	813,306	519,565	1,369,016	417,716	198,063
Net increase (decrease) in cash and cash equivalents	1,383	-6,033	-1,121	3,729	-8,505
Cash and cash equivalents, beginning of period	10,440	11,561	11,561	7,832	16,337
Cash and cash equivalents, end of period	11,823	5,528	10,440	11,561	7,832
Reportable Entity | NGL Energy Partners LP (Parent)
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-8,180	-8,312	-16,625	-12,428
INVESTING ACTIVITIES:
Acquisitions of businesses, including acquired working capital, net of cash acquired		-334,085	-334,154	-452,087	-291,097
Net cash used in investing activities		-334,085	-334,154	-452,087	-291,097
FINANCING ACTIVITIES:
Issuance of notes				250,000
Debt issuance costs	-269	-133	-645	-777
Contributions	395	504	765	510
Distributions to owners	-111,008	-60,258
Proceeds from sale of common units, net of offering costs	370,446	415,089	650,155	-642	74,759
Net changes in advances with consolidated entities	-249,724	-11,459	-153,225	286,991	238,816
Net cash provided by financing activities	9,840	343,743	351,960	464,474	291,097
Net increase (decrease) in cash and cash equivalents	1,660	1,346	1,181	-41
Cash and cash equivalents, beginning of period	1,181			41	41
Cash and cash equivalents, end of period	2,841	1,346	1,181		41
Reportable Entity | NGL Energy Finance Corp
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-15,383
FINANCING ACTIVITIES:
Issuance of notes	400,000		450,000
Debt issuance costs	-7,209		-12,286
Net changes in advances with consolidated entities	-377,408		-437,714
Net cash provided by financing activities	15,383
Reportable Entity | Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	-56,019	-44,607	99,754	140,794	90,477
INVESTING ACTIVITIES:
Purchases of long-lived assets	-81,710	-37,180	-118,455	-59,903	-6,667
Acquisitions of businesses, including acquired working capital, net of cash acquired	-657,514	-56,237	-932,373	-38,718	-6,304
Cash flows from commodity derivatives	-4,327	-19,074
Proceeds from sales of assets	8,741	2,223	12,884	5,080	1,238
Investments in unconsolidated entities	-6,106		-11,515
Distributions of capital from unconsolidated entities	2,774
Net cash used in investing activities	-729,488	-110,268	-1,083,284	-81,962	-4,923
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	1,923,500	1,061,500	2,545,500	1,227,975	478,900
Payments on revolving credit facilities	-1,766,000	-893,000	-2,101,000	-964,475	-329,900
Proceeds from borrowings on other long-term debt		780	780	634
Payments on other long-term debt	-4,173	-4,499	-8,802	-4,837	-1,278
Debt issuance costs	-1,720	-2,085	-11,664	-19,412	-2,380
Net changes in advances with consolidated entities	632,995	-15,123	556,238	-295,105	-239,476
Net cash provided by financing activities	784,602	147,573	981,052	-55,220	-94,134
Net increase (decrease) in cash and cash equivalents	-905	-7,302	-2,478	3,612	-8,580
Cash and cash equivalents, beginning of period	8,728	11,206	11,206	7,594	16,174
Cash and cash equivalents, end of period	7,823	3,904	8,728	11,206	7,594
Reportable Entity | Non-Guarantor Subsidiaries
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	17,947	4,175	2,107	4,268	-148
INVESTING ACTIVITIES:
Purchases of long-lived assets	-1,141	-30,219	-46,693	-12,572	-877
Acquisitions of businesses, including acquired working capital, net of cash acquired	-1,250	-2,283	-2,283
Proceeds from sales of assets		1	11,776
Investments in unconsolidated entities	-20,284
Distributions of capital from unconsolidated entities	1,875
Net cash used in investing activities	-20,800	-32,501	-37,935	-12,572	-877
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facilities	56,000
Payments on revolving credit facilities	-38,000
Proceeds from borrowings on other long-term debt		100	100	19
Payments on other long-term debt	-2	-8	-17
Contributions		1,940	2,060	403	440
Distributions to owners		-365
Distributions to noncontrolling interest partners	-8,654
Net changes in advances with consolidated entities	-5,863	26,582	34,701	8,114	660
Net cash provided by financing activities	3,481	28,249	36,004	8,462	1,100
Net increase (decrease) in cash and cash equivalents	628	-77	176	158	75
Cash and cash equivalents, beginning of period	531	355	355	197	122
Cash and cash equivalents, end of period	$1,159	$278	$531	$355	$197

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	12 Months Ended	6 Months Ended	1 Months Ended	2 Months Ended
	Mar. 31, 2013	Sep. 30, 2014	Nov. 30, 2014	Nov. 30, 2014	Dec. 31, 2014
		item	item	item
Subsequent events
Cash paid for water facilities	$14,000,000
Water Solutions Facility
Subsequent events
Number of water disposal facilities acquired		4
Cash paid for water facilities		82,900,000
Subsequent event | Sale of natural gas liquids terminals
Subsequent events
Loss on disposal					29,000,000
Loss on disposal allocated to property, plant and equipment					21,000,000
Loss on disposal allocated to goodwill					8,000,000
Subsequent event | Water Solutions Facility
Subsequent events
Number of water disposal facilities acquired			5	5
Cash paid for water facilities			$65,000,000	$52,200,000