NGL Energy Partners (NGL) 10-Q 2023 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2022

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________ to __________

Commission File Number: 001-35172

NGL Energy Partners LP

(Exact Name of Registrant as Specified in Its Charter)

Delaware		27-3427920
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)
6120 South Yale Avenue, Suite 805
Tulsa,	Oklahoma	74136
(Address of Principal Executive Offices)		(Zip Code)

(918) 481-1119

(Registrant’s Telephone Number, Including Area Code)

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class	Trading Symbols	Name of Each Exchange on Which Registered
Common units representing Limited Partner Interests	NGL	New York Stock Exchange
Fixed-to-floating rate cumulative redeemable perpetual preferred units	NGL-PB	New York Stock Exchange
Fixed-to-floating rate cumulative redeemable perpetual preferred units	NGL-PC	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.   Yes ☒   No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).   Yes ☒   No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	o	Accelerated filer	x
Non-accelerated filer	o	Smaller reporting company	☐
		Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.   ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).   Yes ☐   No ☒

At February 6, 2023, there were 131,321,742 common units issued and outstanding.

TABLE OF CONTENTS

PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Unaudited Condensed Consolidated Balance Sheets at December 31, 2022 and March 31, 2022	3
	Unaudited Condensed Consolidated Statements of Operations for the three months and nine months ended December 31, 2022 and 2021	4
	Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) for the three months and nine months ended December 31, 2022 and 2021	5
	Unaudited Condensed Consolidated Statements of Changes in Equity for the three months and nine months ended December 31, 2022 and 2021	6
	Unaudited Condensed Consolidated Statements of Cash Flows for the nine months ended December 31, 2022 and 2021	8
	Notes to Unaudited Condensed Consolidated Financial Statements	9
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	59
Item 4.	Controls and Procedures	61
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	62
Item 1A.	Risk Factors	62
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	62
Item 3.	Defaults Upon Senior Securities	62
Item 4.	Mine Safety Disclosures	62
Item 5.	Other Information	62
Item 6.	Exhibits	63
SIGNATURES		64

i

Forward-Looking Statements

This Quarterly Report on Form 10-Q (“Quarterly Report”) contains various forward-looking statements and information that are based on our beliefs and those of our general partner, as well as assumptions made by and information currently available to us. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. Certain words in this Quarterly Report such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “plan,” “project,” “will,” and similar expressions and statements regarding our plans and objectives for future operations, identify forward-looking statements. Although we and our general partner believe such forward-looking statements are reasonable, neither we nor our general partner can assure they will prove to be correct. Forward-looking statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those expected. Among the key risk factors that may affect our consolidated financial position and results of operations are:

•the prices of crude oil, natural gas liquids, gasoline, diesel, biodiesel and energy prices generally;

•the general level of demand, and the availability of supply, for crude oil, natural gas liquids, gasoline, diesel, and biodiesel;

•the level of crude oil and natural gas drilling and production in areas where we have operations and facilities;

•the ability to obtain adequate supplies of products if an interruption in supply or transportation occurs and the availability of capacity to transport products to market areas;

•the effect of weather conditions on supply and demand for crude oil, natural gas liquids, gasoline, diesel, and biodiesel;

•the effect of natural disasters, earthquakes, hurricanes, tornados, lightning strikes, or other significant weather events;

•the availability of local, intrastate, and interstate transportation infrastructure with respect to our transportation services;

•the availability, price, and marketing of competing fuels;

•the effect of energy conservation efforts on product demand;

•energy efficiencies and technological trends;

•issuance of executive orders, changes in applicable laws, regulations and policies, including tax, environmental, transportation, and employment regulations, or new interpretations by regulatory agencies concerning such laws and regulations and the effect of such laws, regulations and policies (now existing or in the future) on our business operations;

•the effect of executive orders and legislative and regulatory actions on hydraulic fracturing, water disposal and transportation, and the treatment of flowback and produced water;

•hazards or operating risks related to transporting and distributing petroleum products that may not be fully covered by insurance;

•the maturity of the crude oil, natural gas liquids, and refined products industries and competition from other markets;

•loss of key personnel;

•the ability to renew contracts with key customers;

•the ability to maintain or increase the margins we realize for our services;

•the ability to renew leases for our leased equipment and storage facilities;

•inflation, interest rates, and general economic conditions (including recessions and other future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers);

•the nonpayment, nonperformance or bankruptcy by our counterparties;

•the availability and cost of capital and our ability to access certain capital sources;

•a deterioration of the credit and capital markets;

1

•the ability to successfully identify and complete accretive acquisitions and organic growth projects, and integrate acquired assets and businesses;

•the costs and effects of legal and administrative proceedings;

•changes in general economic conditions, including market and macroeconomic disruptions resulting from global pandemics and related governmental responses; and

•political pressure and influence of environmental groups upon policies and decisions related to the production, gathering, refining, processing, fractionation, transportation and sale of crude oil, refined products, natural gas, natural gas liquids, gasoline, diesel or biodiesel.

You should not put undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this Quarterly Report. Except as may be required by state and federal securities laws, we undertake no obligation to publicly update or revise any forward-looking statements as a result of new information, future events, or otherwise. When considering forward-looking statements, please review the risks discussed under Part I, Item 1A–“Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended March 31, 2022.

2

PART I - FINANCIAL INFORMATION

Item 1.    Financial Statements

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Balance Sheets

(in Thousands, except unit amounts)

	December 31, 2022		March 31, 2022
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	4,534	$	3,822
Accounts receivable-trade, net of allowance for expected credit losses of $2,455 and $2,626, respectively	1,129,294		1,123,163
Accounts receivable-affiliates	10,257		8,591
Inventories	238,073		251,277
Prepaid expenses and other current assets	135,980		159,486
Total current assets	1,518,138		1,546,339
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $1,000,765 and $887,006, respectively	2,400,508		2,462,390
GOODWILL	744,439		744,439
INTANGIBLE ASSETS, net of accumulated amortization of $563,075 and $507,285, respectively	1,078,631		1,135,354
INVESTMENTS IN UNCONSOLIDATED ENTITIES	22,769		21,897
OPERATING LEASE RIGHT-OF-USE ASSETS	85,576		114,124
OTHER NONCURRENT ASSETS	64,030		45,802
Total assets	$	5,914,091	$	6,070,345
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Accounts payable-trade	$	952,506	$	1,084,837
Accounts payable-affiliates	65		73
Accrued expenses and other payables	174,400		140,719
Advance payments received from customers	20,957		7,934
Current maturities of long-term debt	303,788		2,378
Operating lease obligations	32,883		41,261
Total current liabilities	1,484,599		1,277,202
LONG-TERM DEBT, net of debt issuance costs of $32,986 and $42,988, respectively, and current maturities	2,921,174		3,350,463
OPERATING LEASE OBLIGATIONS	53,518		72,784
OTHER NONCURRENT LIABILITIES	103,378		104,346
COMMITMENTS AND CONTINGENCIES (NOTE 7)
CLASS D 9.00% PREFERRED UNITS, 600,000 and 600,000 preferred units issued and outstanding, respectively	551,097		551,097
EQUITY:
General partner, representing a 0.1% interest, 131,453 and 130,827 notional units, respectively	(52,484)		(52,478)
Limited partners, representing a 99.9% interest, 131,321,742 and 130,695,970 common units issued and outstanding, respectively	488,221		401,486
Class B preferred limited partners, 12,585,642 and 12,585,642 preferred units issued and outstanding, respectively	305,468		305,468
Class C preferred limited partners, 1,800,000 and 1,800,000 preferred units issued and outstanding, respectively	42,891		42,891
Accumulated other comprehensive loss	(439)		(308)
Noncontrolling interests	16,668		17,394
Total equity	800,325		714,453
Total liabilities and equity	$	5,914,091	$	6,070,345

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

3

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Operations

(in Thousands, except unit and per unit amounts)

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
REVENUES:
Water Solutions	$	180,242	$	130,653	$	511,231	$	397,089
Crude Oil Logistics	531,613		607,203		1,971,767		1,715,657
Liquids Logistics	1,427,385		1,434,020		4,163,072		3,301,922
Total Revenues	2,139,240		2,171,876		6,646,070		5,414,668
COST OF SALES:
Water Solutions	2,534		5,030		13,679		21,791
Crude Oil Logistics	471,891		556,531		1,808,460		1,591,877
Liquids Logistics	1,385,943		1,388,760		4,057,360		3,187,039
Total Cost of Sales	1,860,368		1,950,321		5,879,499		4,800,707
OPERATING COSTS AND EXPENSES:
Operating	81,353		72,807		237,371		207,610
General and administrative	17,216		18,925		50,601		46,149
Depreciation and amortization	69,327		68,480		204,105		222,145
Loss on disposal or impairment of assets, net	8,306		12,233		15,791		93,463
Operating Income	102,670		49,110		258,703		44,594
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities	1,213		119		3,094		765
Interest expense	(75,920)		(68,379)		(211,528)		(204,004)
Gain on early extinguishment of liabilities, net	2,667		9		6,808		1,131
Other income, net	28,100		24		28,731		2,003
Income (Loss) Before Income Taxes	58,730		(19,117)		85,808		(155,511)
INCOME TAX BENEFIT (EXPENSE)	252		135		(113)		820
Net Income (Loss)	58,982		(18,982)		85,695		(154,691)
LESS: NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS	(448)		63		(790)		(705)
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	$	58,534	$	(18,919)	$	84,905	$	(155,396)
NET INCOME (LOSS) ALLOCATED TO COMMON UNITHOLDERS - BASIC (NOTE 3)	$	26,007	$	(45,233)	$	(5,571)	$	(232,361)
NET INCOME (LOSS) ALLOCATED TO COMMON UNITHOLDERS - DILUTED (NOTE 3)	$	26,123	$	(45,233)	$	(5,571)	$	(232,361)
BASIC INCOME (LOSS) PER COMMON UNIT	$	0.20	$	(0.35)	$	(0.04)	$	(1.79)
DILUTED INCOME (LOSS) PER COMMON UNIT	$	0.19	$	(0.35)	$	(0.04)	$	(1.79)
BASIC WEIGHTED AVERAGE COMMON UNITS OUTSTANDING	131,015,658		129,810,245		130,802,920		129,666,303
DILUTED WEIGHTED AVERAGE COMMON UNITS OUTSTANDING	134,485,325		129,810,245		130,802,920		129,666,303

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

4

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)

(in Thousands)

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
Net income (loss)	$	58,982	$	(18,982)	$	85,695	$	(154,691)
Other comprehensive income (loss)	1		(4)		(131)		(48)
Comprehensive income (loss)	$	58,983	$	(18,986)	$	85,564	$	(154,739)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

5

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Equity

Three Months and Nine Months Ended December 31, 2022

(in Thousands, except unit amounts)

			Limited Partners
			Preferred			Common
	General Partner		Units	Amount		Units	Amount		Accumulated Other Comprehensive Income (Loss)		Noncontrolling Interests		Total Equity
BALANCE AT MARCH 31, 2022	$	(52,478)	14,385,642	$	348,359	130,695,970	$	401,486	$	(308)	$	17,394	$	714,453
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(975)		(975)
Equity issued pursuant to incentive compensation plan (Note 8)	—		—	—		—	497		—		—		497
Net (loss) income	(5)		—	—		—	22,866		—		245		23,106
Other comprehensive loss	—		—	—		—	—		(50)		—		(50)
BALANCE AT JUNE 30, 2022	(52,483)		14,385,642	348,359		130,695,970	424,849		(358)		16,664		737,031
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(274)		(274)
Equity issued pursuant to incentive compensation plan (Note 8)	—		—	—		—	479		—		—		479
Net (loss) income	(27)		—	—		—	3,537		—		97		3,607
Other comprehensive loss	—		—	—		—	—		(82)		—		(82)
BALANCE AT SEPTEMBER 30, 2022	(52,510)		14,385,642	348,359		130,695,970	428,865		(440)		16,487		740,761
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(267)		(267)
Common unit repurchases and cancellations (Note 8)	—		—	—		(31,828)	(42)		—		—		(42)
Equity issued pursuant to incentive compensation plan (Note 8)	—		—	—		657,600	890		—		—		890
Net income	26		—	—		—	58,508		—		448		58,982
Other comprehensive income	—		—	—		—	—		1		—		1
BALANCE AT DECEMBER 31, 2022	$	(52,484)	14,385,642	$	348,359	131,321,742	$	488,221	$	(439)	$	16,668	$	800,325

6

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Equity

Three Months and Nine Months Ended December 31, 2021

(in Thousands, except unit amounts)

			Limited Partners
			Preferred			Common
	General Partner		Units	Amount		Units	Amount		Accumulated Other Comprehensive Income (Loss)		Noncontrolling Interests		Total Equity
BALANCE AT MARCH 31, 2021	$	(52,189)	14,385,642	$	348,359	129,593,939	$	582,784	$	(266)	$	69,471	$	948,159
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(444)		(444)
Sawtooth joint venture disposition	—		—	—		—	—		—		(51,097)		(51,097)
Equity issued pursuant to incentive compensation plan	—		—	—		—	960		—		—		960
Net (loss) income	(159)		—	—		—	(134,781)		—		438		(134,502)
Other comprehensive income	—		—	—		—	—		8		—		8
BALANCE AT JUNE 30, 2021	(52,348)		14,385,642	348,359		129,593,939	448,963		(258)		18,368		763,084
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(513)		(513)
Equity issued pursuant to incentive compensation plan	—		—	—		—	1,048		—		—		1,048
Net (loss) income	(27)		—	—		—	(1,510)		—		330		(1,207)
Other comprehensive loss	—		—	—		—	—		(52)		—		(52)
BALANCE AT SEPTEMBER 30, 2021	(52,375)		14,385,642	348,359		129,593,939	448,501		(310)		18,185		762,360
Distributions to noncontrolling interest owners	—		—	—		—	—		—		(388)		(388)
Common unit repurchases and cancellations	—		—	—		(8,901)	(20)		—		—		(20)
Equity issued pursuant to incentive compensation plan	—		—	—		399,100	749		—		—		749
Net loss	(47)		—	—		—	(18,872)		—		(63)		(18,982)
Other comprehensive loss	—		—	—		—	—		(4)		—		(4)
BALANCE AT DECEMBER 31, 2021	$	(52,422)	14,385,642	$	348,359	129,984,138	$	430,358	$	(314)	$	17,734	$	743,715

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

7

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Cash Flows

(in Thousands)

	Nine Months Ended December 31,
	2022		2021
OPERATING ACTIVITIES:
Net income (loss)	$	85,695	$	(154,691)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization, including amortization of debt issuance costs	217,028		235,357
Gain on early extinguishment of liabilities, net	(6,808)		(1,131)
Equity-based compensation expense	1,866		(1,044)
Loss on disposal or impairment of assets, net	15,791		93,463
Change in provision for expected credit losses	(485)		88
Net adjustments to fair value of commodity derivatives	13,879		42,875
Equity in earnings of unconsolidated entities	(3,094)		(765)
Distributions of earnings from unconsolidated entities	2,568		2,178
Lower of cost or net realizable value adjustments	3,050		6,534
Other	701		1,593
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable-trade and affiliates	(4,778)		(316,477)
Inventories	(24,904)		(194,053)
Other current and noncurrent assets	6,285		33,792
Accounts payable-trade and affiliates	(131,086)		294,230
Other current and noncurrent liabilities	31,157		(15,038)
Net cash provided by operating activities	206,865		26,911
INVESTING ACTIVITIES:
Capital expenditures	(122,362)		(107,480)
Net settlements of commodity derivatives	28,521		(60,972)
Proceeds from sales of assets	22,120		8,419
Proceeds from divestitures of businesses and investments, net	—		63,489
Investments in unconsolidated entities	(346)		(350)
Distributions of capital from unconsolidated entities	—		393
Net cash used in investing activities	(72,067)		(96,501)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facility	1,432,000		1,342,000
Payments on revolving credit facility	(1,392,000)		(1,190,000)
Repayment and repurchase of senior unsecured notes	(168,047)		(60,149)
Payments on other long-term debt	(1,931)		(6,772)
Debt issuance costs	(1,340)		(12,503)
Distributions to noncontrolling interest owners	(1,516)		(1,345)
Common unit repurchases and cancellations	(42)		(20)
Payments to settle contingent consideration liabilities	(1,204)		(994)
Principal payments of finance leases	(6)		—
Net cash (used in) provided by financing activities	(134,086)		70,217
Net increase in cash and cash equivalents	712		627
Cash and cash equivalents, beginning of period	3,822		4,829
Cash and cash equivalents, end of period	$	4,534	$	5,456
Supplemental cash flow information:
Cash interest paid	$	163,203	$	162,053
Income taxes paid (net of income tax refunds)	$	3,088	$	1,896
Supplemental non-cash investing and financing activities:
Accrued capital expenditures	$	7,398	$	9,949

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

8

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements

Note 1—Organization and Operations

NGL Energy Partners LP (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership. NGL Energy Holdings LLC serves as our general partner (“GP”). At December 31, 2022, our operations included three segments:

•Our Water Solutions segment transports, treats, recycles and disposes of produced and flowback water generated from crude oil and natural gas production. We also sell produced water for reuse and recycle and brackish non-potable water to our producer customers to be used in their crude oil exploration and production activities. As part of processing water, we aggregate and sell recovered crude oil, also known as skim oil. We also dispose of solids such as tank bottoms, drilling fluids and drilling muds and perform other ancillary services such as truck and frac tank washouts. Our activities in this segment are underpinned by long-term, fixed fee contracts and acreage dedications, some of which contain minimum volume commitments with leading oil and gas companies including large, investment grade producer customers.

•Our Crude Oil Logistics segment purchases crude oil from producers and marketers and transports it to refineries or for resale at pipeline injection stations, storage terminals, barge loading facilities, rail facilities, refineries, and other trade hubs, and provides storage, terminaling, and transportation services through its owned assets. Our activities in this segment are supported by certain long-term, fixed rate contracts which include minimum volume commitments on our owned and leased pipelines.

•Our Liquids Logistics segment conducts supply operations for natural gas liquids, refined petroleum products and biodiesel to a broad range of commercial, retail and industrial customers across the United States and Canada. These operations are conducted through our 24 owned terminals, third-party storage and terminal facilities, nine common carrier pipelines and a fleet of leased railcars. We also provide services for marine exports of butane through our facility located in Chesapeake, Virginia. Our propane pipeline in Michigan was completed on August 8, 2022.

Note 2—Significant Accounting Policies

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include our accounts and those of our controlled subsidiaries. Intercompany transactions and account balances have been eliminated in consolidation. Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. We also own an undivided interest in a crude oil pipeline, and include our proportionate share of assets, liabilities, and expenses related to this pipeline in our unaudited condensed consolidated financial statements.

Our unaudited condensed consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim consolidated financial information in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the unaudited condensed consolidated financial statements exclude certain information and notes required by GAAP for complete annual consolidated financial statements. However, we believe that the disclosures made are adequate to make the information presented not misleading. The unaudited condensed consolidated financial statements include all adjustments that we consider necessary for a fair presentation of our consolidated financial position, results of operations and cash flows for the interim periods presented. Such adjustments consist only of normal recurring items, unless otherwise disclosed in this Quarterly Report. The unaudited condensed consolidated balance sheet at March 31, 2022 was derived from our audited consolidated financial statements for the fiscal year ended March 31, 2022 included in our Annual Report on Form 10-K (“Annual Report”) filed with the SEC on June 6, 2022.

These interim unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report. Due to the seasonal nature of certain of our operations and other factors, the results of operations for interim periods are not necessarily indicative of the results of operations to be expected for future periods or for the full fiscal year ending March 31, 2023.

Use of Estimates

The preparation of consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amount of assets and liabilities reported at the date of the consolidated financial statements and the amount of revenues and expenses reported during the periods presented.

9

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Critical accounting estimates we make in the preparation of our unaudited condensed consolidated financial statements include, among others, determining the impairment of goodwill and long-lived assets, useful lives and recoverability of property, plant and equipment and amortizable intangible assets, the fair value of derivative instruments, estimating certain revenues, the fair value of asset retirement obligations, the fair value of assets and liabilities acquired in acquisitions, the recoverability of inventories, the collectibility of accounts and notes receivable and accruals for environmental matters. Although we believe these estimates are reasonable, actual results could differ from those estimates.

Significant Accounting Policies

Our significant accounting policies are consistent with those disclosed in Note 2 of our audited consolidated financial statements included in our Annual Report.

Income Taxes

We qualify as a partnership for income tax purposes. As such, we generally do not pay United States federal income tax. Rather, each owner reports his or her share of our income or loss on his or her individual tax return. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined, as we do not have access to information regarding each partner’s basis in the Partnership.

We have a deferred tax liability of $42.0 million and $43.5 million at December 31, 2022 and March 31, 2022, respectively, as a result of acquiring corporations in connection with certain of our acquisitions, which is included within other noncurrent liabilities in our unaudited condensed consolidated balance sheets. The deferred tax liability is the tax effected cumulative temporary difference between the GAAP basis and tax basis of the acquired assets within the corporation. For GAAP purposes, certain of the acquired assets will be depreciated and amortized over time which will lower the GAAP basis. The deferred tax benefit recorded during the nine months ended December 31, 2022 was $1.6 million with an effective tax rate of 25.1%. The deferred tax benefit recorded during the nine months ended December 31, 2021 was $2.0 million with an effective tax rate of 22.9%.

We evaluate uncertain tax positions for recognition and measurement in the unaudited condensed 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 unaudited condensed consolidated financial statements. We had no uncertain tax positions that required recognition in our unaudited condensed consolidated financial statements at December 31, 2022 or March 31, 2022.

Inventories

Our inventories are valued at the lower of cost or net realizable value, with cost determined using either the weighted-average cost or the first in, first out (FIFO) methods, including the cost of transportation and storage, and with net realizable value defined as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. In performing this analysis, we consider fixed-price forward commitments.

Inventories consist of the following at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Propane	$	97,706	$	43,971
Crude oil	69,905		135,485
Butane	39,294		33,144
Biodiesel	16,598		20,474
Diesel	5,192		3,504
Ethanol	798		3,503
Other	8,580		11,196
Total	$	238,073	$	251,277

10

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Investments in Unconsolidated Entities

Investments we do not control, but can exercise significant influence over, are accounted for using the equity method of accounting. Investments in partnerships and limited liability companies, unless our investment is considered to be minor, and investments in unincorporated joint ventures are also accounted for using the equity method of accounting.

Our investments in unconsolidated entities consist of the following at the dates indicated:

Entity	Segment	Ownership Interest	December 31, 2022		March 31, 2022
			(in thousands)
Water services and land company	Water Solutions	50%	$	15,963	$	15,714
Water services and land company	Water Solutions	10%	3,615		2,863
Water services and land company	Water Solutions	50%	2,281		2,210
Aircraft company (1)	Corporate and Other	50%	362		538
Water services company	Water Solutions	50%	409		409
Natural gas liquids terminal company	Liquids Logistics	50%	139		163
Total			$	22,769	$	21,897

(1)    This is an investment with a related party.

Other Noncurrent Assets

Other noncurrent assets consist of the following at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Linefill (1)	$	53,772	$	28,065
Minimum shipping fees - pipeline commitments (2)	5,696		8,899
Loan receivable (3)	—		3,147
Other	4,562		5,691
Total	$	64,030	$	45,802

(1)    Represents minimum volumes of product we are required to leave on certain third-party owned pipelines under long-term shipment commitments. At December 31, 2022 and March 31, 2022, linefill consisted of 717,686 and 423,978 barrels of crude oil, respectively. The increase was due primarily to capitalizing additional crude oil barrels as a result of increased requirements by third-party owned pipelines. Linefill held in pipelines we own is included within property, plant and equipment (see Note 4).

(2)    Represents the noncurrent portion of minimum shipping fees paid in excess of volumes shipped, or deficiency credits, for a contract with a crude oil pipeline operator. This amount can be recovered when volumes shipped exceed the minimum monthly volume commitment (see Note 7). At December 31, 2022, the deficiency credit was $10.0 million, of which $4.3 million is recorded within prepaid expenses and other current assets in our unaudited condensed consolidated balance sheet.

(3)    Represents the noncurrent portion of a loan receivable, net of an allowance for an expected credit loss, with a former related party. During the nine months ended December 31, 2022, we received payments totaling $3.1 million to extinguish this loan receivable and we recorded a loss of $0.2 million within loss on disposal or impairment of assets, net to write off the remaining balance.

Accrued Expenses and Other Payables

Accrued expenses and other payables consist of the following at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Accrued interest	$	91,873	$	56,104
Accrued compensation and benefits	20,543		18,417
Excise and other tax liabilities	13,753		10,451
Derivative liabilities	13,688		27,108
Product exchange liabilities	10,765		853
Other	23,778		27,786
Total	$	174,400	$	140,719

11

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Recent Accounting Pronouncements

In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, “Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity.” This ASU (i) simplifies an issuer’s accounting for convertible instruments by eliminating two of the three models in Accounting Standards Codification (“ASC”) 470-20 that require separate accounting for embedded conversion features, (ii) amends diluted earnings per share calculations for convertible instruments by requiring the use of the if-converted method and (iii) simplifies the settlement assessment entities are required to perform on contracts that can potentially settle in an entity’s own equity by removing certain requirements. We adopted this guidance on April 1, 2022, using the modified retrospective method. Under our Class D Preferred Unit (as defined in Note 8) agreement, we are permitted to issue common units to redeem a portion of the outstanding Class D Preferred Units. Using the if-converted method, we expect our calculation of earnings per unit to be impacted by both an increase in the number of diluted weighted average common units outstanding and a decrease in the amount of Class D Preferred Unit distributions, when they are determined to be dilutive. Other than the potential impact to our future earnings per unit calculations, the adoption of this guidance did not impact our financial position, results of operations or cash flows related to any debt or preferred units issued prior to adoption.

In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” The ASU provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference the London Interbank Offered Rate (“LIBOR”) interest rate or another reference rate expected to be discontinued because of reference rate reform. This guidance was to be effective prospectively upon issuance through December 31, 2022 and applied from the beginning of an interim period that included the issuance date of this ASU. However, in December 2022, the FASB issued ASU 2022-06, “Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848” which deferred the sunset date from December 31, 2022 to December 31, 2024. All other provisions of ASU 2020-04 were unchanged. On April 13, 2022, the ABL Facility (as defined herein) was amended to replace the LIBOR benchmark with the SOFR (as defined herein) benchmark (as discussed further in Note 6). We are continuing to evaluate the effect that this guidance will have on our financial position, results of operations and cash flows.

Note 3—Income (Loss) Per Common Unit

The following table presents our calculation of basic and diluted weighted average common units outstanding for the periods indicated:

	Three Months Ended December 31,		Nine Months Ended December 31,
	2022	2021	2022	2021
Weighted average common units outstanding during the period:
Common units - Basic	131,015,658	129,810,245	130,802,920	129,666,303
Effect of Dilutive Securities:
Partial redemption of Class D Preferred Units (1)	3,469,667	—	—	—
Common units - Diluted	134,485,325	129,810,245	130,802,920	129,666,303

(1)    Under the if-converted method, amount represents the number of common units that would be issued to partially redeem outstanding Class D Preferred Units. Per the amended and restated limited partnership agreement (the “Partnership Agreement”), the Partnership can redeem up to 50% of the outstanding Class D Preferred Units, but is limited in the number of common units that can be used (the lower of 15% of the outstanding common units or 10 times the 30-day average daily trading volume) for the redemption.

For the three months ended December 31, 2022, the service awards and warrants were considered antidilutive and for the three months ended December 31, 2021 all convertible securities were considered antidilutive. For the nine months ended December 31, 2022 and 2021, all potential common units or convertible securities were considered antidilutive.

12

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Our income (loss) per common unit is as follows for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands, except unit and per unit amounts)
Net income (loss)	$	58,982	$	(18,982)	$	85,695	$	(154,691)
Less: Net (income) loss attributable to noncontrolling interests	(448)		63		(790)		(705)
Net income (loss) attributable to NGL Energy Partners LP	58,534		(18,919)		84,905		(155,396)
Less: Distributions to preferred unitholders (1)	(32,501)		(26,361)		(90,482)		(77,198)
Less: Net (income) loss allocated to GP (2)	(26)		47		6		233
Net income (loss) allocated to common unitholders - basic	26,007		(45,233)		(5,571)		(232,361)
Plus: Distributions to preferred unitholders (3)	116		—		—		—
Net income (loss) allocated to common unitholders - diluted	$	26,123	$	(45,233)	$	(5,571)	$	(232,361)
Basic income (loss) per common unit	$	0.20	$	(0.35)	$	(0.04)	$	(1.79)
Diluted income (loss) per common unit	$	0.19	$	(0.35)	$	(0.04)	$	(1.79)
Basic weighted average common units outstanding	131,015,658		129,810,245		130,802,920		129,666,303
Diluted weighted average common units outstanding	134,485,325		129,810,245		130,802,920		129,666,303

(1)    Includes cumulative distributions for the three months and nine months ended December 31, 2022 and 2021 which were earned but not declared or paid (see Note 8 for a further discussion of the suspension of common unit and preferred unit distributions).

(2)    Net (income) loss allocated to the GP includes distributions to which it is entitled as the holder of incentive distribution rights.

(3)    Under the if-converted method, amount represents the Class D Preferred Unit distributions that would be eliminated due to the partial redemption of the Class D Preferred Units.

Note 4—Property, Plant and Equipment

Our property, plant and equipment consists of the following at the dates indicated:

Description	Estimated Useful Lives			December 31, 2022		March 31, 2022
	(in years)			(in thousands)
Natural gas liquids terminal and storage assets	2	-	30	$	176,894	$	173,199
Pipeline and related facilities	30	-	40	265,642		265,643
Vehicles and railcars (1)	3	-	25	92,851		93,126
Water treatment facilities and equipment	3	-	30	2,111,554		2,040,687
Crude oil tanks and related equipment	2	-	30	237,310		236,805
Barges and towboats	5	-	30	146,023		138,778
Information technology equipment	3	-	7	38,111		48,664
Buildings and leasehold improvements	3	-	40	149,342		151,071
Land				92,840		100,038
Tank bottoms and linefill (2)				39,794		30,443
Other	3	-	20	12,138		15,252
Construction in progress				38,774		55,690
				3,401,273		3,349,396
Accumulated depreciation				(1,000,765)		(887,006)
Net property, plant and equipment				$	2,400,508	$	2,462,390

(1)    Includes a finance lease right-of-use asset of $0.1 million.

(2)    Tank bottoms, which are product volumes required for the operation of storage tanks, are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. Linefill, which represents our portion of the product volume required for the operation of the proportionate share of a pipeline we own, is recorded at historical cost.

13

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes depreciation expense and capitalized interest expense for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Depreciation expense	$	50,005	$	48,404	$	145,862	$	156,855
Capitalized interest expense	$	250	$	149	$	740	$	805

We record (gains) losses from the sales of property, plant and equipment and any write-downs in value due to impairment within loss on disposal or impairment of assets, net in our unaudited condensed consolidated statement of operations. The following table summarizes (gains) losses on the disposal or impairment of property, plant and equipment by segment for the periods indicated:

	Three Months Ended December 31, 2022		Nine Months Ended December 31, 2022
	(in thousands)
Water Solutions	$	9,467	$	20,137
Crude Oil Logistics	(213)		(1,909)
Liquids Logistics	54		51
Corporate and Other	(694)		(1,214)
Total	$	8,614	$	17,065

Note 5—Intangible Assets

Our intangible assets consist of the following at the dates indicated:

		December 31, 2022						March 31, 2022
Description	Weighted- Average Remaining Useful Life	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
	(in years)	(in thousands)
Amortizable:
Customer relationships	19.0	$	1,200,919	$	(480,437)	$	720,482	$	1,200,919	$	(436,837)	$	764,082
Customer commitments	21.5	192,000		(26,880)		165,120		192,000		(21,120)		170,880
Pipeline capacity rights	20.9	7,799		(2,362)		5,437		7,799		(2,167)		5,632
Rights-of-way and easements	31.0	94,854		(14,396)		80,458		91,664		(12,201)		79,463
Water rights	16.6	99,869		(24,940)		74,929		99,869		(20,404)		79,465
Executory contracts and other agreements	23.3	21,431		(4,414)		17,017		20,931		(3,014)		17,917
Non-compete agreements	0.3	1,100		(1,027)		73		7,000		(6,487)		513
Debt issuance costs (1)	3.2	23,479		(8,619)		14,860		22,202		(5,055)		17,147
Total amortizable		1,641,451		(563,075)		1,078,376		1,642,384		(507,285)		1,135,099
Non-amortizable:
Trade names		255		—		255		255		—		255
Total		$	1,641,706	$	(563,075)	$	1,078,631	$	1,642,639	$	(507,285)	$	1,135,354

(1)    Includes debt issuance costs related to the ABL Facility (as defined herein). Debt issuance costs related to the fixed-rate notes are reported as a reduction of the carrying amount of long-term debt.

14

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Amortization expense is as follows for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
Recorded In	2022		2021		2022		2021
	(in thousands)
Depreciation and amortization	$	19,322	$	20,076	$	58,243	$	65,290
Cost of sales	68		69		205		213
Interest expense	1,203		1,283		3,564		3,658
Operating expenses	62		62		185		185
Total	$	20,655	$	21,490	$	62,197	$	69,346

The following table summarizes expected amortization of our intangible assets at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	20,647
2024	76,228
2025	68,007
2026	65,091
2027	60,388
2028	57,535
Thereafter	730,480
Total	$	1,078,376

Note 6—Long-Term Debt

Our long-term debt consists of the following at the dates indicated:

	December 31, 2022						March 31, 2022
	Face Amount		Unamortized Debt Issuance Costs (1)		Book Value		Face Amount		Unamortized Debt Issuance Costs (1)		Book Value
	(in thousands)
Senior secured notes:
7.500% Notes due 2026 (“2026 Senior Secured Notes”)	$	2,050,000	$	(28,314)	$	2,021,686	$	2,050,000	$	(35,140)	$	2,014,860
Asset-based revolving credit facility (“ABL Facility”)	156,000		—		156,000		116,000		—		116,000
Senior unsecured notes:
7.500% Notes due 2023 (“2023 Notes”)	301,885		(633)		301,252		475,702		(1,873)		473,829
6.125% Notes due 2025 (“2025 Notes”)	380,020		(1,825)		378,195		380,020		(2,456)		377,564
7.500% Notes due 2026 (“2026 Notes”)	330,902		(2,796)		328,106		332,402		(3,460)		328,942
Other long-term debt	39,774		(51)		39,723		41,705		(59)		41,646
	3,258,581		(33,619)		3,224,962		3,395,829		(42,988)		3,352,841
Less: Current maturities	304,421		(633)		303,788		2,378		—		2,378
Long-term debt	$	2,954,160	$	(32,986)	$	2,921,174	$	3,393,451	$	(42,988)	$	3,350,463

(1)    Debt issuance costs related to the ABL Facility are reported within intangible assets, rather than as a reduction of the carrying amount of long-term debt.

2026 Senior Secured Notes

The 2026 Senior Secured Notes bear interest at 7.5%, which is payable on February 1 and August 1 of each year, beginning on August 1, 2021. The 2026 Senior Secured Notes mature on February 1, 2026. The 2026 Senior Secured Notes were issued pursuant to an indenture dated February 4, 2021 (the “Indenture”).

The 2026 Senior Secured Notes are secured by first priority liens on substantially all of our assets other than our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets and second priority liens on our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets.

15

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The Indenture contains covenants that, among other things, limit our ability to: pay distributions or make other restricted payments or repurchase stock; incur or guarantee additional indebtedness or issue disqualified stock or certain preferred stock; make certain investments; create or incur liens; sell assets; enter into restrictions affecting the ability of restricted subsidiaries to make distributions, make loans or advances or transfer assets to the guarantors (including the Partnership); enter into certain transactions with our affiliates; designate restricted subsidiaries as unrestricted subsidiaries; and merge, consolidate or transfer or sell all or substantially all of our assets. The Indenture specifically restricts our ability to pay distributions until our total leverage ratio (as defined in the Indenture) for the most recently ended four full fiscal quarters at the time of the distribution is not greater than 4.75 to 1.00. These covenants are subject to a number of important exceptions and qualifications.

Compliance

At December 31, 2022, we were in compliance with the covenants under the Indenture.

ABL Facility

The ABL Facility is subject to a borrowing base, which includes a sub-limit for letters of credit. The initial commitments under the ABL Facility were $500.0 million. On April 13, 2022, we amended the ABL Facility to increase the commitments to $600.0 million under the accordion feature within the ABL Facility. As part of the amendment, we agreed to reduce the commitments back to $500.0 million on or before March 31, 2023. In addition, the sub-limit for letters of credit was increased to $250.0 million and the LIBOR benchmark was replaced with an adjusted forward-looking term rate based on the secured overnight financing rate (“SOFR”) as the interest rate benchmark. The ABL Facility is secured by a lien on substantially all of our assets, including among other things, a first priority lien on our accounts receivable, inventory, pledged deposit accounts, cash and cash equivalents, renewable energy tax credits and related assets and a second priority lien on all of our other assets. At December 31, 2022, $156.0 million had been borrowed under the ABL Facility and we had letters of credit outstanding of approximately $168.4 million. The ABL Facility is scheduled to mature at the earliest of (a) February 4, 2026 or (b) 91 days prior to the earliest maturity date in respect to any of our indebtedness in an aggregate principal amount of $50.0 million or greater, if such indebtedness is outstanding at such time, subject to certain exceptions.

At December 31, 2022, the borrowings under the ABL Facility had a weighted average interest rate of 7.37% calculated as the prime rate of 7.50% plus a margin of 1.75% on the alternate base borrowings and the weighted average SOFR of 4.33% plus a margin of 2.75% for the SOFR borrowings. On December 31, 2022, the interest rate in effect on letters of credit was 2.75%.

The ABL Facility contains various affirmative and negative covenants, including financial reporting requirements and limitations on indebtedness, liens, mergers, consolidations, liquidations and dissolutions, sales of assets, distributions and other restricted payments, investments (including acquisitions) and transactions with affiliates. The ABL Facility contains, as the only financial covenant, a fixed charge coverage ratio that is tested based on the financial statements for the most recently ended fiscal quarter upon the occurrence and during the continuation of a Cash Dominion Event (as defined in the ABL Facility). At December 31, 2022, no Cash Dominion Event had occurred.

Compliance

At December 31, 2022, we were in compliance with the covenants under the ABL Facility.

Senior Unsecured Notes

The senior unsecured notes include the 2023 Notes, which mature on November 1, 2023, the 2025 Notes, which mature on March 1, 2025 and the 2026 Notes, which mature on April 15, 2026 (collectively, the “Senior Unsecured Notes”).

16

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Repurchases

The following table summarizes repurchases of Senior Unsecured Notes for the periods indicated:

	Three Months Ended December 31, 2022		Nine Months Ended December 31, 2022
	(in thousands)
2023 Notes
Notes repurchased	$	97,457	$	173,817
Cash paid (excluding payments of accrued interest)	$	94,575	$	166,926
Gain on early extinguishment of debt (1)	$	2,667	$	6,444
2026 Notes
Notes repurchased	$	—	$	1,500
Cash paid (excluding payments of accrued interest)	$	—	$	1,121
Gain on early extinguishment of debt (2)	$	—	$	364

(1)    Gain on early extinguishment of debt for the three months and nine months ended December 31, 2022 is inclusive of the write-off of debt issuance costs of $0.2 million and $0.4 million, respectively. The gain is reported within gain on early extinguishment of liabilities, net within our unaudited condensed consolidated statements of operations.

(2)    Gain on early extinguishment of debt for the nine months ended December 31, 2022 is inclusive of the write-off of debt issuance costs of less than $0.1 million. The gain is reported within gain on early extinguishment of liabilities, net within our unaudited condensed consolidated statements of operations.

Subsequent to December 31, 2022, we have repurchased $98.5 million of the 2023 Notes and as of February 8, 2023, the outstanding balance of the 2023 Notes is $203.4 million.

We expect to pay off the remaining outstanding 2023 Notes no later than June 30, 2023, using cash flows from operations, and if needed, borrowings under our ABL Facility. Proceeds generated from other cash flow positive initiatives currently being pursued, such as sales of non-core assets, may also be used for additional debt reductions.

Redemption

We currently have the right to redeem all of the outstanding 2023 Notes at 100% of the principal amount plus accrued and unpaid interest. As of March 1, 2023, we will have the right to redeem all or a portion of the outstanding 2025 Notes at 100% of the principal amount plus accrued and unpaid interest. As of April 15, 2024, we will have the right to redeem all or a portion of the outstanding 2026 Notes at 100% of the principal amount plus accrued and unpaid interest.

Compliance

At December 31, 2022, we were in compliance with the covenants under all of the Senior Unsecured Notes indentures.

Other Long-Term Debt

On October 29, 2020, we entered into an equipment loan for $45.0 million which bears interest at a rate of 8.6% and is secured by certain of our barges and towboats. We have an aggregate principal balance of $39.8 million at December 31, 2022. The loan matures on November 1, 2027.

17

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Debt Maturity Schedule

The scheduled maturities of our long-term debt are as follows at December 31, 2022:

Fiscal Year Ending March 31,	2026 Senior Secured Notes		ABL Facility		Senior Unsecured Notes		Other Long-Term Debt		Total
	(in thousands)
2023 (three months)	$	—	$	—	$	—	$	446	$	446
2024	—		—		301,885		2,816		304,701
2025	—		—		380,020		3,068		383,088
2026	2,050,000		156,000		—		3,343		2,209,343
2027	—		—		330,902		3,642		334,544
2028	—		—		—		26,459		26,459
Total	$	2,050,000	$	156,000	$	1,012,807	$	39,774	$	3,258,581

Amortization of Debt Issuance Costs

Amortization expense for debt issuance costs related to long-term debt was $3.0 million and $3.0 million during the three months ended December 31, 2022 and 2021, respectively, and $9.0 million and $9.2 million during the nine months ended December 31, 2022 and 2021, respectively.

The following table summarizes expected amortization of debt issuance costs at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	2,908
2024	11,319
2025	10,808
2026	8,531
2027	46
2028	7
Total	$	33,619

Note 7—Commitments and Contingencies

Legal Contingencies

In August 2015, LCT Capital, LLC (“LCT”) filed a lawsuit against the GP and the Partnership seeking payment for investment banking services relating to the purchase of TransMontaigne Inc. and related assets in July 2014. After pre-trial rulings, LCT was limited to pursuing claims of (i) quantum meruit (the value of the services rendered by LCT) and (ii) fraudulent misrepresentation against the defendants. Following a jury trial conducted in Delaware state court from July 23, 2018 through August 1, 2018, the jury returned a verdict consisting of an award of $4.0 million for quantum meruit and $29.0 million for fraudulent misrepresentation, subject to statutory interest. On December 5, 2019, in response to the defendants’ post-trial motion, the Court issued an Order overturning the jury’s damages award and ordering the case to be set for a damages-only trial (the “December 5th Order”). Both parties filed applications with the trial court asking the trial court to certify the December 5th Order for interlocutory, immediate review by the Appellate Court. On January 7, 2020, the Supreme Court of Delaware (“Supreme Court”) entered an Order accepting an interlocutory appeal of various issues relating to both the quantum meruit and fraudulent misrepresentation verdicts. The Supreme Court heard oral arguments of the parties on November 4, 2020, took the matters presented under advisement and on January 28, 2021, issued a ruling that (a) LCT is not entitled to “benefit-of-the-bargain” damages on its fraud claim; (b) LCT is not entitled to receive fraudulent misrepresentation damages separate from its quantum meruit damages; (c) the trial court abused its discretion when it ordered a new trial on damages relating to LCT’s claim of fraudulent misrepresentation; and (d) the trial court properly ordered a new trial on LCT’s claim of quantum meruit damages. The trial that is limited to the claim of quantum meruit damages, started on February 6, 2023. Any allocation of the ultimate verdict award, if any, between the GP and the Partnership will be made by the board of directors of our GP once all information is available to it and after the new trial, any post-trial and/or any appellate process has concluded and the verdict is final as a matter of law. As of December 31, 2022, we have accrued $2.5 million related to this matter.

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The Partnership is a party defendant to a purported class action complaint filed in the federal court in the Northern District of Oklahoma styled Gary R. Underwood, Successor Trustee for the James L. Price Revocable Living Trust, on behalf of the Trust and all others similarly situated v. NGL Energy Partners LP, Case No. 4:21-cv-00135-CVE-SH. This case seeks class certification on behalf of owners who allege the Partnership’s Crude Oil Logistics group violated Oklahoma’s Production Revenue Standards Act when it failed to include statutory interest on proceeds payments it made to certain mineral owners and to state unclaimed property divisions for oil purchased from certain Oklahoma wells. A substantial portion of the statutory interest claimed to be owed in the lawsuit related to suspended proceeds we inherited from our predecessors and remitted to various state unclaimed property divisions in 2016. With no admission of liability or wrongdoing, but only to avoid the expense and uncertainty of future litigation, the Partnership entered into a settlement agreement in this case to resolve all claims made against it by the plaintiff and the proposed class. We have agreed to pay the sum of approximately $8.4 million to the plaintiff and the proposed class, and we accrued the amount as of December 31, 2022. The settlement agreement is subject to court approval and a full fairness hearing will be held in the coming months.

We are party to various other claims, legal actions, and complaints arising in the ordinary course of business. In the opinion of our management, the ultimate resolution of these claims, legal actions, and complaints, after consideration of amounts accrued, insurance coverage, and other arrangements, is not expected to have a material adverse effect on our consolidated financial position, results of operations or cash flows. However, the outcome of such matters is inherently uncertain, and estimates of our liabilities may change materially as circumstances develop.

Environmental Matters

At December 31, 2022, we have an environmental liability, measured on an undiscounted basis, of $1.7 million, which is recorded within accrued expenses and other payables in our unaudited condensed consolidated balance sheet. Our operations are subject to extensive federal, state, and local environmental laws and regulations. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our business, and there can be no assurance that we will not incur significant costs. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations, could result in substantial costs. Accordingly, we have adopted policies, practices, and procedures in the areas of pollution control, product safety, occupational health, and the handling, storage, use, and disposal of hazardous materials designed to prevent material environmental or other damage, and to limit the financial liability that could result from such events. However, some risk of environmental or other damage is inherent in our business.

Asset Retirement Obligations

We have contractual and regulatory obligations at certain facilities for which we have to perform remediation, dismantlement, or removal activities when the assets are retired. Our liability for asset retirement obligations is discounted to present value. To calculate the liability, we make estimates and assumptions about the retirement cost and the timing of retirement. Changes in our assumptions and estimates may occur as a result of the passage of time and the occurrence of future events.

The following table summarizes changes in our asset retirement obligation, which is reported within other noncurrent liabilities in our unaudited condensed consolidated balance sheets (in thousands):

Balance at March 31, 2022	$	29,941
Liabilities incurred	2,367
Liabilities associated with disposed assets (1)	(878)
Liabilities settled	(171)
Accretion expense	2,195
Balance at December 31, 2022	$	33,454

(1)    Relates to the sale of six saltwater disposal wells and other long-lived assets within our Water Solutions business.

In addition to the obligations described above, we may be obligated to remove facilities or perform other remediation upon retirement of certain other assets. However, the fair value of the asset retirement obligation cannot currently be reasonably estimated because the settlement dates are indeterminable. We will record an asset retirement obligation for these assets in the periods in which settlement dates are reasonably determinable.

19

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Pipeline Capacity Agreements

We have noncancelable agreements with crude oil pipeline operators, which guarantee us minimum monthly shipping capacity on the pipelines. As a result, we are required to pay the minimum shipping fees if actual shipments are less than our allotted capacity. Under certain agreements we have the ability to recover minimum shipping fees previously paid if our shipping volumes exceed the minimum monthly shipping commitment during each month remaining under the agreement, with some contracts containing provisions that allow us to continue shipping up to six months after the maturity date of the contract in order to recapture previously paid minimum shipping delinquency fees. We currently have an asset recorded in prepaid expenses and other current assets and in other noncurrent assets in our unaudited condensed consolidated balance sheet for minimum shipping fees paid in both the current and previous periods that are expected to be recovered in future periods by exceeding the minimum monthly volumes (see Note 2).

The following table summarizes future minimum throughput payments under these agreements at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	9,466
2024	38,495
2025	33,588
Total	$	81,549

Sales and Purchase Contracts

We have entered into product sales and purchase contracts for which we expect the parties to physically settle and deliver the inventory in future periods.

At December 31, 2022, we had the following commodity purchase commitments:

	Crude Oil (1)			Natural Gas Liquids
	Value		Volume (in barrels)	Value		Volume (in gallons)
	(in thousands)
Fixed-Price Commodity Purchase Commitments:
2023 (three months)	$	74,358	1,086	$	10,651	11,112
2024	—		—	7,367		8,904
2025	—		—	2,829		3,486
2026	—		—	1,982		2,730
2027	—		—	1,808		2,520
Total	$	74,358	1,086	$	24,637	28,752
Index-Price Commodity Purchase Commitments:
2023 (three months)	$	1,465,229	18,666	$	368,303	373,268
2024	2,592,153		34,575	224,896		247,447
2025	1,582,749		22,775	6,910		10,500
2026	659,019		10,410	—		—
Total	$	6,299,150	86,426	$	600,109	631,215

(1)    Our crude oil index-price purchase commitments exceed our crude oil index-price sales commitments (presented below) due primarily to our long-term purchase commitments for crude oil that we purchase and ship on the Grand Mesa Pipeline. As these purchase commitments are deliver-or-pay contracts, whereby our counterparty is required to pay us for any volumes not delivered, we have not entered into corresponding long-term sales contracts for volumes we may not receive.

20

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

At December 31, 2022, we had the following commodity sale commitments:

	Crude Oil			Natural Gas Liquids
	Value		Volume (in barrels)	Value		Volume (in gallons)
	(in thousands)
Fixed-Price Commodity Sale Commitments:
2023 (three months)	$	72,426	1,050	$	153,699	119,489
2024	—		—	26,197		26,608
2025	—		—	4,035		4,548
2026	—		—	2,304		3,056
2027	—		—	2,065		2,805
Total	$	72,426	1,050	$	188,300	156,506
Index-Price Commodity Sale Commitments:
2023 (three months)	$	1,332,521	17,188	$	390,313	340,449
2024	1,310,390		16,672	31,860		33,009
2025	743,470		10,220	—		—
2026	27,493		390	—		—
Total	$	3,413,874	44,470	$	422,173	373,458

We account for the contracts shown in the tables above using the normal purchase and normal sale election. Under this accounting policy election, we do not record the physical contracts at fair value at each balance sheet date; instead, we record the purchase or sale at the contracted value once the delivery occurs. Contracts in the tables above may have offsetting derivative contracts (described in Note 9) or inventory positions (described in Note 2).

Certain other forward purchase and sale contracts do not qualify for the normal purchase and normal sale election. These contracts are recorded at fair value in our unaudited condensed consolidated balance sheet and are not included in the tables above. These contracts are included in the derivative disclosures in Note 9 and represent $35.0 million of our prepaid expenses and other current assets and $13.6 million of our accrued expenses and other payables at December 31, 2022.

Other Commitments

We have noncancelable agreements for product storage, railcar spurs and real estate. The following table summarizes future minimum payments under these agreements at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	2,070
2024	10,004
2025	3,707
2026	1,342
2027	1,328
2028	1,269
Thereafter	4,222
Total	$	23,942

As part of the acquisition of Hillstone Environmental Partners, LLC, we assumed an obligation to pay a quarterly subsidy payment in the event that specified volumetric thresholds are not exceeded at a third-party facility (the “Subsidy Agreement”). For the three months and nine months ended December 31, 2022, we recorded $0.5 million and $1.3 million, respectively, and for the three months and nine months ended December 31, 2021, we recorded $0.6 million and $1.7 million, respectively, within operating expense in our unaudited condensed consolidated statements of operations. The Subsidy Agreement expired on December 31, 2022.

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Note 8—Equity

Partnership Equity

The Partnership’s equity consists of a 0.1% GP interest and a 99.9% limited partner interest, which consists of common units. Our GP has the right, but not the obligation, to contribute a proportionate amount of capital to the Partnership to maintain its 0.1% GP interest. Our GP is not required to guarantee or pay any of our debts and obligations. At December 31, 2022, we owned 8.69% of our GP.

General Partner Contributions

In connection with the issuance of common units for the vesting of restricted units during the nine months ended December 31, 2022, we issued 626 notional units to our GP for less than $0.1 million in order to maintain its 0.1% interest in the Partnership.

Suspension of Common Unit and Preferred Unit Distributions

The board of directors of our GP temporarily suspended all distributions (common unit distributions which began with the quarter ended December 31, 2020 and preferred unit distributions which began with the quarter ended March 31, 2021) in order to deleverage our balance sheet and meet the financial performance ratios set within the Indenture of the 2026 Senior Secured Notes, as discussed further in Note 6.

Class B Preferred Units

As of December 31, 2022, there were 12,585,642 of our Class B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (“Class B Preferred Units”) outstanding.

On July 1, 2022, the Class B Preferred Units distribution rate changed from a fixed rate of 9.00% to a floating rate of the three-month LIBOR interest rate (3.75% for the quarter ended December 31, 2022) plus a spread of 7.21%. For the quarter ended December 31, 2022, we did not declare or pay distributions to the holders of the Class B Preferred Units, thus the quarterly distribution for December 31, 2022 is $0.6855 and the cumulative distribution since suspension for each Class B Preferred Unit is $4.6541. In addition, the amount of cumulative but unpaid distributions shall continue to accumulate at the then applicable rate until all unpaid distributions have been paid in full. The total amount due as of December 31, 2022 is $63.1 million.

Class C Preferred Units

As of December 31, 2022, there were 1,800,000 of our Class C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (“Class C Preferred Units”) outstanding.

The current distribution rate for the Class C Preferred Units is 9.625% per year of the $25.00 liquidation preference per unit (equal to $2.41 per unit per year). For the quarter ended December 31, 2022, we did not declare or pay distributions to the holders of the Class C Preferred Units, thus the quarterly distribution for December 31, 2022 is $0.6016 and the cumulative distribution since suspension for each Class C Preferred Unit is $4.8125. In addition, the amount of cumulative but unpaid distributions shall continue to accumulate at the then applicable rate until all unpaid distributions have been paid in full. The total amount due as of December 31, 2022 is $9.4 million.

Class D Preferred Units

As of December 31, 2022, there were 600,000 preferred units (“Class D Preferred Units”) and warrants exercisable to purchase an aggregate of 25,500,000 common units outstanding.

The current distribution rate for the Class D Preferred Units increased on July 1, 2022 from 9.00% to 10.00% per year per unit (equal to $100.00 per every $1,000 in unit value per year), and includes an additional 1.50% rate increase due to us exceeding the adjusted total leverage ratio and due to a Class D distribution payment default, as defined within the amended Partnership Agreement. For the quarter ended December 31, 2022, we did not declare or pay distributions to the holders of the Class D Preferred Units, thus the average quarterly distribution at December 31, 2022 is $29.92 and the average cumulative distribution since suspension for each Class D Preferred unit is $222.42. In addition, the amount of cumulative but unpaid

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

distributions shall continue to accumulate at the then applicable rate until all unpaid distributions have been paid in full. The total amount due as of December 31, 2022 is $145.9 million.

Equity-Based Incentive Compensation

Our GP adopted a long-term incentive plan (“LTIP”), which allowed for the issuance of equity-based compensation. Our GP granted certain restricted units to employees and directors, which vest in tranches, subject to the continued service of the recipients through the vesting date (the “Service Awards”). The Service Awards may also vest upon a change of control, at the discretion of the board of directors of our GP. No distributions accrue to or are paid on the Service Awards during the vesting period. The LTIP expired on May 10, 2021.

The following table summarizes the Service Award activity during the nine months ended December 31, 2022:

	Number of Units	Weighted-Average Grant Date Fair Value Per Unit
Unvested Service Award units at March 31, 2022	2,188,800	$2.15
Units vested and issued	(657,600)	$2.15
Units forfeited	(218,750)	$2.15
Unvested Service Award units at December 31, 2022	1,312,450	$2.15

In connection with the vesting of certain Service Awards during the nine months ended December 31, 2022, 31,828 of the newly-vested common units were surrendered by employees in satisfaction of less than $0.1 million of employee withholding taxes paid by the Partnership. Pursuant to the expiration of the LTIP discussed below, those surrendered units are not available for future grants.

As the LTIP expired on May 10, 2021, we had no common units available for grant for the nine months ended December 31, 2022.

As of December 31, 2022, there are 656,225 unvested Service Award units which are expected to vest during the fiscal year ending March 31, 2023 and 656,225 unvested Service Award units which are expected to vest during the fiscal year ending March 31, 2024. Also, any current unvested Service Awards that are forfeited or canceled will not be available for future grants.

Service Awards are valued at the average of the high/low sales price as of the grant date less the present value of the expected distribution stream over the vesting period using a risk-free interest rate. We record the expense for each Service Award on a straight-line basis over the requisite period for the entire award (that is, over the requisite service period of the last separately vesting portion of the award), ensuring that the amount of compensation cost recognized at any date at least equals the portion of the grant date value of the award that is vested at that date.

During the three months ended December 31, 2022 and 2021, we recorded compensation expense related to Service Award units of $0.9 million and $0.7 million, respectively. During the nine months ended December 31, 2022 and 2021, we recorded compensation expense related to Service Award units of $1.9 million and $2.8 million, respectively.

For the unvested Service Award units at December 31, 2022, we had estimated future expense of $0.9 million which we expect to record during the fiscal year ending March 31, 2023 and $1.2 million which we expect to record during the fiscal year ending March 31, 2024.

Note 9—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.

23

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Commodity Derivatives

The following table summarizes the estimated fair values of our commodity derivative assets and liabilities reported in our unaudited condensed consolidated balance sheets at the dates indicated:

	December 31, 2022				March 31, 2022
	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
	(in thousands)
Level 1 measurements	$	59,865	$	(9,175)	$	73,353	$	(47,585)
Level 2 measurements	36,415		(14,166)		51,968		(27,372)
	96,280		(23,341)		125,321		(74,957)
Netting of counterparty contracts (1)	(9,713)		9,713		(47,585)		47,585
Net cash collateral (held) provided	(37,712)		(98)		839		—
Commodity derivatives	$	48,855	$	(13,726)	$	78,575	$	(27,372)

(1)    Relates to commodity derivative assets and liabilities that are expected to be net settled on an exchange or through a netting arrangement with the counterparty. Our physical contracts that do not qualify as normal purchase normal sale transactions are not subject to such netting arrangements.

The following table summarizes the accounts that include our commodity derivative assets and liabilities in our unaudited condensed consolidated balance sheets at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Prepaid expenses and other current assets	$	48,855	$	78,575
Accrued expenses and other payables	(13,688)		(27,108)
Other noncurrent liabilities	(38)		(264)
Net commodity derivative asset	$	35,129	$	51,203

24

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes our open commodity derivative contract positions at the dates indicated. We do not account for these derivatives as hedges.

Contracts	Settlement Period	Net Long (Short) Notional Units (in barrels)	Fair Value of Net Assets (Liabilities)
		(in thousands)
At December 31, 2022:
Crude oil fixed-price (1)	January 2023–December 2023	12	$	53,476
Propane fixed-price (1)	January 2023–December 2024	(71)	(6,820)
Refined products fixed-price (1)	January 2023–December 2023	(436)	510
Butane fixed-price (1)	January 2023–January 2024	(230)	3,855
Other	January 2023–August 2024		21,918
			72,939
Net cash collateral held			(37,810)
Net commodity derivative asset			$	35,129
At March 31, 2022:
Crude oil fixed-price (1)	April 2022–December 2023	(1,330)	$	35,662
Propane fixed-price (1)	April 2022–December 2023	184	3,785
Refined products fixed-price (1)	April 2022–December 2022	685	(6,063)
Butane fixed-price (1)	April 2022–December 2023	(268)	(1,711)
Other	April 2022–March 2023		18,691
			50,364
Net cash collateral provided			839
Net commodity derivative asset			$	51,203

(1)    We may have fixed price physical purchases, including inventory, offset by floating price physical sales or floating price physical purchases offset by fixed price physical sales. These contracts are derivatives we have entered into as an economic hedge against the risk of mismatches between fixed and floating price physical obligations.

During the three months ended December 31, 2022 and 2021, we recorded net losses of $0.8 million and $2.2 million, respectively, from our commodity derivatives to revenues and cost of sales in our unaudited condensed consolidated statements of operations. During the nine months ended December 31, 2022 and 2021, we recorded net losses of $13.9 million and $42.9 million, respectively, from our commodity derivatives to revenues and cost of sales in our unaudited condensed consolidated statements of operations.

Credit Risk

We have credit policies that we believe minimize our overall credit risk, including an evaluation of potential counterparties’ financial condition (including credit ratings), collateral requirements under certain circumstances, and the use of industry standard master netting agreements, which allow for offsetting counterparty receivable and payable balances for certain transactions. At December 31, 2022, our primary counterparties were retailers, resellers, energy marketers, producers, refiners, and dealers. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, as the counterparties may be similarly affected by changes in economic, regulatory or other conditions. If a counterparty does not perform on a contract, we may not realize amounts that have been recorded in our unaudited condensed consolidated balance sheets and recognized in our net income.

Interest Rate Risk

The ABL Facility is variable-rate debt with interest rates that are generally indexed to the prime rate or SOFR, an adjusted forward-looking term rate based on the secured overnight financing rate. At December 31, 2022, we had $156.0 million of outstanding borrowings under the ABL Facility at a weighted average interest rate of 7.37%.

On July 1, 2022, the Class B Preferred Units distribution rate changed from a fixed rate of 9.00% to a floating rate of the three-month LIBOR interest rate (3.75% for the quarter ended December 31, 2022) plus a spread of 7.21%.

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

For our Class C Preferred Units, distributions on and after April 15, 2024 will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR interest rate (or alternative rate as determined in the Partnership Agreement) plus a spread of 7.384%. On or after July 1, 2024, the holders of our Class D Preferred Units can elect, from time to time, for the distributions to be calculated based on a floating rate equal to the applicable three-month LIBOR interest rate (or alternative rate as determined in the Partnership Agreement) plus a spread of 7.00% (“Class D Variable Rate”, as defined in the Partnership Agreement). Each Class D Variable Rate election shall be effective for at least four quarters following such election.

Fair Value of Fixed-Rate Notes

The following table provides fair value estimates of our fixed-rate notes at December 31, 2022 (in thousands):

Senior Secured Notes:
2026 Senior Secured Notes	$	1,823,830
Senior Unsecured Notes:
2023 Notes	$	292,577
2025 Notes	$	305,916
2026 Notes	$	253,692

For the 2026 Senior Secured Notes and Senior Unsecured Notes, the fair value estimates were developed based on publicly traded quotes and would be classified as Level 2 in the fair value hierarchy.

Note 10—Segments

Our operations are organized into three reportable segments: (i) Water Solutions, (ii) Crude Oil Logistics and (iii) Liquids Logistics, consistent with the manner in which our chief operating decision maker evaluates performance and allocates resources. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Our Liquids Logistics reportable segment includes operating segments that have been aggregated based on the nature of the products and services provided. Operating income of these segments is reviewed by the chief operating decision maker to evaluate performance and make business decisions. Intersegment transactions are recorded based on prices negotiated between the segments and are eliminated upon consolidation.

See Note 1 for a discussion of the products and services of our reportable segments. The remainder of our business operations is presented as “Corporate and Other” and consists of certain corporate expenses that are not allocated to the reportable segments. The following table summarizes revenues related to our segments for the periods indicated:

26

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Revenues:
Water Solutions:
Topic 606 revenues
Disposal service fees	$	136,211	$	102,917	$	382,483	$	303,106
Sale of recovered crude oil	30,284		17,865		96,205		48,848
Sale of water	6,127		6,842		15,300		31,694
Other service revenues	7,620		3,029		17,243		13,441
Total Water Solutions revenues	180,242		130,653		511,231		397,089
Crude Oil Logistics:
Topic 606 revenues
Crude oil sales	507,793		588,729		1,906,963		1,660,225
Crude oil transportation and other	23,676		18,826		67,083		56,088
Non-Topic 606 revenues	1,876		2,153		5,562		6,518
Elimination of intersegment sales	(1,732)		(2,505)		(7,841)		(7,174)
Total Crude Oil Logistics revenues	531,613		607,203		1,971,767		1,715,657
Liquids Logistics:
Topic 606 revenues
Refined products sales	609,686		503,348		1,994,123		1,340,725
Propane sales	331,031		396,457		751,609		776,157
Butane sales	241,462		296,481		593,654		582,358
Other product sales	120,454		155,556		436,549		409,452
Service revenues	384		361		7,027		8,849
Non-Topic 606 revenues	124,368		81,817		380,110		185,705
Elimination of intersegment sales	—		—		—		(1,324)
Total Liquids Logistics revenues	1,427,385		1,434,020		4,163,072		3,301,922
Total revenues	$	2,139,240	$	2,171,876	$	6,646,070	$	5,414,668

The following tables summarize depreciation and amortization expense (including amortization expense recorded within interest expense, cost of sales and operating expenses in Note 5 and Note 6) and operating income (loss) by segment for the periods indicated.

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Depreciation and Amortization:
Water Solutions	$	52,653	$	50,877	$	153,951	$	164,651
Crude Oil Logistics	11,664		12,166		35,193		37,029
Liquids Logistics	3,485		3,824		10,399		15,627
Corporate and Other	5,816		6,066		17,485		18,050
Total	$	73,618	$	72,933	$	217,028	$	235,357
Operating Income (Loss):
Water Solutions	$	59,721	$	19,851	$	160,454	$	60,206
Crude Oil Logistics	35,096		21,291		87,012		37,941
Liquids Logistics	20,513		23,158		48,806		(18,790)
Corporate and Other	(12,660)		(15,190)		(37,569)		(34,763)
Total	$	102,670	$	49,110	$	258,703	$	44,594

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NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes additions to property, plant and equipment and intangible assets by segment for the periods indicated. This information has been prepared on the accrual basis, and includes property, plant and equipment and intangible assets acquired in acquisitions.

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Water Solutions	$	19,292	$	21,254	$	100,989	$	81,807
Crude Oil Logistics	1,516		515		7,793		1,986
Liquids Logistics	880		4,248		4,685		10,308
Corporate and Other	984		341		1,734		1,504
Total	$	22,672	$	26,358	$	115,201	$	95,605

The following tables summarize long-lived assets, net (consisting of property, plant and equipment, intangible assets, operating lease right-of-use assets and goodwill) and total assets by segment at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Long-lived assets, net:
Water Solutions	$	2,884,147	$	2,970,911
Crude Oil Logistics	1,017,379		1,050,546
Liquids Logistics (1)	367,460		385,783
Corporate and Other	40,168		49,067
Total	$	4,309,154	$	4,456,307

(1)    Includes $14.2 million and $17.1 million of non-US long-lived assets at December 31, 2022 and March 31, 2022, respectively.

	December 31, 2022		March 31, 2022
	(in thousands)
Total assets:
Water Solutions	$	3,062,983	$	3,130,659
Crude Oil Logistics	1,865,022		1,952,048
Liquids Logistics (1)	929,646		888,927
Corporate and Other	56,440		98,711
Total	$	5,914,091	$	6,070,345

(1)    Includes $58.0 million and $40.2 million of non-US total assets at December 31, 2022 and March 31, 2022, respectively.

Note 11—Transactions with Affiliates

The following table summarizes our related party transactions for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Purchases from equity method investees	$	372	$	243	$	1,251	$	784
Purchases from entities affiliated with management	$	—	$	957	$	—	$	1,045

Accounts receivable from affiliates consist of the following at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
NGL Energy Holdings LLC	$	9,630	$	8,483
Equity method investees	627		107
Entities affiliated with management	—		1
Total	$	10,257	$	8,591

28

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Accounts payable to affiliates consist of the following at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Equity method investees	$	64	$	27
Entities affiliated with management	1		46
Total	$	65	$	73

Other Related Party Transactions

Guarantee of Outstanding Loan for KAIR2014 LLC (“KAIR2014”)

In connection with the purchase of our 50% interest in an aircraft company, KAIR2014, we executed a joint and several guarantee for the benefit of the lender for KAIR2014’s outstanding loan. The other owner of KAIR2014, our Chief Executive Officer, H. Michael Krimbill, is a party to a similar guarantee. This guarantee obligates us for the payment and performance of KAIR2014 with respect to the repayment of the loan. As of December 31, 2022, the outstanding balance of the loan is approximately $2.3 million. Payments are made monthly, reducing the outstanding balance, and the loan matures in September 2023. As the guarantee is joint and several, we could be liable for the entire outstanding balance of the loan. The loan is collateralized by the airplane owned by KAIR2014 and in the event of a default, the lender could seek payment in full from us. As of December 31, 2022, no accrual has been recorded related to this guarantee.

Note 12—Revenue from Contracts with Customers

We recognize revenue for services and products under revenue contracts as our obligations to either perform services or deliver or sell products under the contracts are satisfied. Our revenue contracts in the scope of ASC 606 primarily have a single performance obligation and we do not receive material amounts of non-cash consideration. Our costs to obtain or fulfill our revenue contracts were not material as of December 31, 2022.

The majority of our revenue agreements are in the scope of ASC 606 and the remainder of our revenue comes from contracts that are accounted for as derivatives under ASC 815 or that contain nonmonetary exchanges or leases in the scope of ASC 845 and ASC 842, respectively. See Note 10 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Liquids Logistics segment includes $3.9 million of net losses related to changes in the mark-to-market value of these contracts recorded during the nine months ended December 31, 2022.

Remaining Performance Obligations

Most of our service contracts are such that we have the right to consideration from a customer in an amount that corresponds directly with the value to the customer of our performance completed to date. Therefore, we utilized the practical expedient in ASC 606-10-55-18 under which we recognize revenue in the amount to which we have the right to invoice. Applying this practical expedient, we are not required to disclose the transaction price allocated to remaining performance obligations under these agreements. The following table summarizes the amount and timing of revenue recognition for such contracts at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	37,188
2024	90,551
2025	81,206
2026	23,041
2027	8,130
2028	1,269
Thereafter	804
Total	$	242,189

29

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Contract Assets and Liabilities

The following tables summarize the balances of our contract assets and liabilities at the dates indicated:

	December 31, 2022		March 31, 2022
	(in thousands)
Accounts receivable from contracts with customers	$	530,676	$	605,384

Contract liabilities balance at March 31, 2022	$	7,667
Payment received and deferred	47,424
Payment recognized in revenue	(34,295)
Contract liabilities balance at December 31, 2022	$	20,796

Note 13—Leases

Lessee Accounting

Our operating lease activity primarily consists of product storage, office space, real estate, railcars, and equipment.

The following table summarizes the components of our lease cost for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Operating lease cost (1)	$	12,436	$	14,180	$	39,596	$	44,474
Variable lease cost (1)	7,397		5,725		21,987		15,978
Short-term lease cost (1)	94		60		242		219
Finance lease cost
Amortization of right-of-use asset (2)	1		—		2		—
Interest on lease obligation (3)	4		—		6		—
Total lease cost	$	19,932	$	19,965	$	61,833	$	60,671

(1)    Included in operating expenses in our unaudited condensed consolidated statements of operations.

(2)    Included in depreciation and amortization expense in our unaudited condensed consolidated statements of operations.

(3)    Included in interest expense in our unaudited condensed consolidated statements of operations.

The following table summarizes maturities of our lease obligations at December 31, 2022 (in thousands):

	Operating		Finance
Fiscal Year Ending March 31,	Leases		Lease (1)
2023 (three months)	$	10,987	$	7
2024	35,071		28
2025	22,041		28
2026	9,895		28
2027	4,593		28
2028	4,016		10
Thereafter	26,763		—
Total lease payments	113,366		129
Less imputed interest	(26,965)		—
Total lease obligations	$	86,401	$	129

(1)    At December 31, 2022, the short-term finance lease obligation of less than $0.1 million is included in accrued expenses and other payables and the long-term finance lease obligation of $0.1 million is included in other noncurrent liabilities.

30

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes supplemental cash flow information related to our leases for the periods indicated:

	Nine Months Ended December 31,
	2022		2021
	(in thousands)
Supplemental Cash Flow Information
Cash paid for amounts included in the measurement of lease obligations
Operating cash outflows from operating leases	$	39,207	$	43,919
Operating cash outflows from finance lease	$	6	$	—
Financing cash outflows from finance lease	$	6	$	—
Right-of-use assets obtained in exchange for lease obligations
Operating leases	$	17,452	$	11,738
Finance lease	$	102	$	—

Lessor Accounting and Subleases

Our lessor arrangements include storage and railcar contracts. We also, from time to time, sublease certain of our storage capacity and railcars to third-parties. Fixed rental revenue is recognized on a straight-line basis over the lease term. During the three months ended December 31, 2022 and 2021, fixed rental revenue was $4.5 million, which includes $2.3 million of sublease revenue, and $3.7 million, which includes $0.5 million of sublease revenue, respectively. During the nine months ended December 31, 2022 and 2021, fixed rental revenue was $11.2 million, which includes $3.4 million of sublease revenue and $10.9 million, which includes $1.1 million of sublease revenue, respectively.

The following table summarizes future minimum lease payments to be received under various noncancelable operating lease agreements at December 31, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (three months)	$	3,143
2024	15,534
2025	4,698
2026	4,017
2027	4,017
2028	4,016
Total	$	35,425

Note 14—Allowance for Current Expected Credit Loss (CECL)

ASU 2016-13 requires that an allowance for expected credit losses be recognized for certain financial assets that reflects the current expected credit loss over the financial asset’s contractual life. The valuation allowance considers the risk of loss, even if remote, and considers past events, current conditions and reasonable and supportable forecasts.

We are exposed to credit losses primarily through sale of products and services and notes receivable from third-parties. A counterparty’s ability to pay is assessed through a credit process that considers the payment terms, the counterparty’s established credit rating or our assessment of the counterparty’s credit worthiness and other risks. We can require prepayment or collateral to mitigate credit risks.

We group our financial assets into pools of counterparties with similar risk characteristics for the purpose of determining the allowance for expected credit losses. Each reporting period, we assess whether a significant change in the risk of expected credit loss has occurred. Among the quantitative and qualitative factors considered in calculating our allowance for expected credit losses are historical financial data, including write-offs and allowances, current conditions, industry risk and current credit ratings. Financial assets will be written off in whole, or in part, when practical recovery efforts have been exhausted and no reasonable expectation of recovery exists. Subsequent recoveries of amounts previously written off are recorded as an increase to the allowance for expected credit losses. We manage receivable pools using past due balances as a key credit quality indicator.

31

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes changes in our allowance for expected credit losses:

	Accounts Receivable - Trade		Notes Receivable and Other
	(in thousands)
Balance at March 31, 2022	$	2,626	$	458
Change in provision for expected credit losses	(27)		(458)
Write-offs charged against the provision	(144)		—
Balance at December 31, 2022	$	2,455	$	—

Note 15—Other Matters

Dispute Settlement

During the three months ended December 31, 2022, we recorded other income of $29.5 million to settle a dispute associated with commercial activities not occurring in the current reporting periods. We received payment on December 29, 2022. This amount is recorded within other income, net in our unaudited condensed consolidated statements of operations for the three months and nine months ended December 31, 2022.

Third-party Loan Receivable

As previously disclosed, we had an outstanding loan receivable, including accrued interest, associated with our interest in a facility that was utilized by a third-party. Due to the bankruptcy of the third-party, we wrote down the remaining outstanding balance to what we expected to collect as an unsecured claim. At March 31, 2022, the outstanding balance of our unsecured claim was $0.6 million, net of an allowance for an expected credit loss, which was recorded within prepaid expenses and other current assets in our consolidated balance sheet. During the three months ended June 30, 2022, we received $1.0 million to settle our unsecured claim and we reversed the allowance for the expected credit loss.

Note 16—Subsequent Events

Subsequent to December 31, 2022, we repurchased $98.5 million of the 2023 Notes. See Note 6 for a further discussion related to the repurchasing of the 2023 Notes.

Item 2.    Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following is a discussion of NGL Energy Partners LP’s (“we,” “us,” “our,” or the “Partnership”) financial condition and results of operations as of and for the three months and nine months ended December 31, 2022. The discussion should be read in conjunction with the unaudited condensed consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q (“Quarterly Report”), as well as Part II, Item 7–“Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended March 31, 2022 (“Annual Report”) filed with the Securities and Exchange Commission (“SEC”) on June 6, 2022.

Overview

We are a Delaware limited partnership. NGL Energy Holdings LLC serves as our general partner (“GP”). At December 31, 2022, our operations included three segments: Water Solutions, Crude Oil Logistics and Liquids Logistics. See Note 1 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion of these businesses.

Global Pandemic and Ukraine War

While the COVID-19 pandemic did not have as significant of an impact on our business and industry in 2022 as it did in prior periods, primarily due to reopening economies and the reduction in oil and natural gas supply, intermittent lockdowns, travel bans and similar restrictions in certain markets from time to time continue to impact our business and cause volatility in commodity prices. Additional factors impacting volatility in commodity prices and production levels include inflation, supply chain issues and the Russia-Ukraine conflict.

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Seismic Activity

The subsurface injection of produced water for disposal has been associated with recent induced seismic events in Texas and New Mexico. While these events have been of relatively low magnitude, industry and relevant state regulators are, nevertheless, taking proactive measures to attempt to prevent similar induced seismic events. More specifically, we are engaged in various collaborative industry efforts with other disposal operators and relevant state regulatory agencies, working to collect and review data, enhance understanding of regional fault systems, and ultimately develop and implement appropriate longer-term mitigation strategies. As part of this effort, we have implemented reductions in injected volumes at certain facilities, and where appropriate have temporarily shut-in facilities. To date, due to the capacity of our integrated system in the affected areas, the diverse locations of our disposal facilities, and the connectivity of our system, our ability to dispose of produced water has not been materially impacted by these actions.

Consolidated Results of Operations

The following table summarizes our unaudited condensed consolidated statements of operations for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Revenues	$	2,139,240	$	2,171,876	$	6,646,070	$	5,414,668
Cost of sales	1,860,368		1,950,321		5,879,499		4,800,707
Operating expenses	81,353		72,807		237,371		207,610
General and administrative expense	17,216		18,925		50,601		46,149
Depreciation and amortization	69,327		68,480		204,105		222,145
Loss on disposal or impairment of assets, net	8,306		12,233		15,791		93,463
Operating income	102,670		49,110		258,703		44,594
Equity in earnings of unconsolidated entities	1,213		119		3,094		765
Interest expense	(75,920)		(68,379)		(211,528)		(204,004)
Gain on early extinguishment of liabilities, net	2,667		9		6,808		1,131
Other income, net	28,100		24		28,731		2,003
Income (loss) before income taxes	58,730		(19,117)		85,808		(155,511)
Income tax benefit (expense)	252		135		(113)		820
Net income (loss)	58,982		(18,982)		85,695		(154,691)
Less: Net (income) loss attributable to noncontrolling interests	(448)		63		(790)		(705)
Net income (loss) attributable to NGL Energy Partners LP	$	58,534	$	(18,919)	$	84,905	$	(155,396)

Items Impacting the Comparability of Our Financial Results

Our current and future results of operations may not be comparable to our historical results of operations for the periods presented due to acquisitions, dispositions and other transactions. Our results of operations for the three months and nine months ended December 31, 2022 are not necessarily indicative of the results of operations to be expected for future periods or for the full fiscal year ending March 31, 2023.

Recent Developments

Repurchases of Senior Unsecured Notes

During the three months ended December 31, 2022, we repurchased $97.5 million of the 7.5% senior unsecured notes due 2023 (“2023 Notes”).

Acquisitions and Dispositions

The following transaction impacted the comparability of our results of operations between our current and prior fiscal years.

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•On June 18, 2021, we sold our approximately 71.5% interest in Sawtooth Caverns, LLC (“Sawtooth”) to a group of buyers.

Subsequent Events

See Note 16 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a discussion of transactions that occurred subsequent to December 31, 2022.

Segment Operating Results for the Three Months Ended December 31, 2022 and 2021

Water Solutions

The following table summarizes the operating results of our Water Solutions segment for the periods indicated:

	Three Months Ended December 31,
	2022		2021		Change
	(in thousands, except per barrel and per day amounts)
Revenues:
Water disposal service fees	$	133,673	$	100,106	$	33,567
Sale of recovered crude oil	30,284		17,865		12,419
Recycled water	5,470		869		4,601
Other revenues	10,815		11,813		(998)
Total revenues	180,242		130,653		49,589
Expenses:
Cost of sales-excluding impact of derivatives	2,534		4,944		(2,410)
Derivative loss	—		86		(86)
Operating expenses	54,665		43,177		11,488
General and administrative expenses	2,772		1,783		989
Depreciation and amortization expense	52,591		50,815		1,776
Loss on disposal or impairment of assets, net	7,959		9,997		(2,038)
Total expenses	120,521		110,802		9,719
Segment operating income	$	59,721	$	19,851	$	39,870
Produced water processed (barrels per day)
Delaware Basin	2,128,673		1,551,621		577,052
Eagle Ford Basin	131,551		110,243		21,308
DJ Basin	151,265		159,332		(8,067)
Other Basins	14,335		18,351		(4,016)
Total	2,425,824		1,839,547		586,277
Recycled water (barrels per day)	167,774		52,854		114,920
Total (barrels per day)	2,593,598		1,892,401		701,197
Skim oil sold (barrels per day)	4,099		2,678		1,421
Service fees for produced water processed ($/barrel) (1)	$	0.60	$	0.59	$	0.01
Recovered crude oil for produced water processed ($/barrel) (1)	$	0.14	$	0.11	$	0.03
Operating expenses for produced water processed ($/barrel) (1)	$	0.25	$	0.26	$	(0.01)

(1)    Total produced water barrels processed during the three months ended December 31, 2022 and 2021 were 223,175,902 and 169,238,413, respectively.

Water Disposal Service Fee Revenues. The increase was due to an increase in produced water volumes processed as a result of increased crude oil production driven by higher crude oil prices and completion activity, primarily in the Delaware Basin as well as higher fees charged for spot volumes.

Recovered Crude Oil Revenues. The increase was due primarily to higher volumes of skim oil barrels sold due to an increase in produced water volumes processed as well as higher realized crude oil prices received from the sale of skim oil barrels. Additionally, an increase in the number of wells completed in our area of operations during the period with increased flowback activity resulted in higher skim oil volumes per barrel of produced water processed.

34

Recycled Water Revenues. Revenue from recycled water includes the sale of produced water and recycled water for use in our customers’ completion activities. The increase was due primarily to increasing demand for water to be used in completions, driven by an increase in drilling and completion activity primarily in the Delaware Basin, and our customers’ transition from brackish non-potable water to recycled water and higher pricing for recycled water.

Other Revenues. Other revenues primarily include brackish non-potable water revenues, water pipeline revenues, land surface use revenues, solids disposal revenues and reimbursements from customer projects. The decrease was due primarily to lower sales of brackish non-potable water related to the termination of a joint marketing agreement as well as our customers transitioning from brackish non-potable water to recycled water, partially offset by reimbursements for construction projects in the current period.

Cost of Sales-Excluding Impact of Derivatives. The decrease was due primarily to lower purchases of brackish non-potable water from third-parties to meet customer needs due to the termination of a joint marketing agreement.

Derivative Loss. We enter into derivatives in our Water Solutions segment to protect against the risk of a decline in the market price of the crude oil we expect to recover when processing produced water and selling recovered skim oil. During the three months ended December 31, 2022, we had no derivative activity. During the three months ended December 31, 2021, we had $1.8 million of net unrealized losses on derivatives and $1.7 million of net realized gains on derivatives.

Operating and General and Administrative Expenses. The increase was due primarily to higher utility, royalty and chemical expenses as a result of the increase in produced water volumes processed. Utility, royalty and chemical expenses, which are three of our largest variable expenses, were not impacted by the rise in inflation due to negotiated long-term utility contracts with fixed rates, royalty contracts with no escalation clauses and a fixed chemical expense per barrel with our chemical provider. The increase was also due to higher severance taxes due to the increase in revenue from recovered crude oil.

Depreciation and Amortization Expense. The increase was due primarily to depreciation of newly developed facilities and infrastructure. This increase was partially offset by certain long-term assets being fully amortized or impaired during the fiscal year ended March 31, 2022 and nine months ended December 31, 2022.

Loss on Disposal or Impairment of Assets, Net. During the three months ended December 31, 2022, we recorded a net loss of $6.1 million primarily related to the sale of certain assets. We also recorded a net loss of $4.0 million to write down the value of two inactive saltwater disposal facilities and damaged equipment at another saltwater disposal facility as well as the abandonment of certain capital projects and the retirement of certain assets. In addition, we recorded a gain of $2.2 million from an insurance recovery for saltwater disposal facility damaged in a prior period. During the three months ended December 31, 2021, we recorded a net loss of $14.3 million primarily related to the write-down of an inactive saltwater disposal facility and damaged equipment and wells at other facilities, abandonment of certain capital projects and the sale of certain other miscellaneous assets and a gain of $4.3 million on the sale of certain land and a landfill permit.

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Crude Oil Logistics

The following table summarizes the operating results of our Crude Oil Logistics segment for the periods indicated:

	Three Months Ended December 31,
	2022		2021		Change
	(in thousands, except per barrel amounts)
Revenues:
Crude oil sales	$	507,793	$	588,729	$	(80,936)
Crude oil transportation and other	25,552		20,979		4,573
Total revenues (1)	533,345		609,708		(76,363)
Expenses:
Cost of sales-excluding impact of derivatives	478,889		556,581		(77,692)
Derivative (gain) loss	(5,266)		2,455		(7,721)
Operating expenses	11,441		13,079		(1,638)
General and administrative expenses	1,244		1,874		(630)
Depreciation and amortization expense	11,664		12,166		(502)
Loss on disposal or impairment of assets, net	277		2,262		(1,985)
Total expenses	498,249		588,417		(90,168)
Segment operating income	$	35,096	$	21,291	$	13,805
Crude oil sold (barrels)	5,955		7,515		(1,560)
Crude oil transported on owned pipelines (barrels)	7,062		7,590		(528)
Crude oil storage capacity - owned and leased (barrels) (2)	5,232		5,232		—
Crude oil storage capacity leased to third-parties (barrels) (2)	2,000		1,501		499
Crude oil inventory (barrels) (2)	892		1,295		(403)
Crude oil sold ($/barrel)	$	85.272	$	78.341	$	6.931
Cost per crude oil sold ($/barrel) (3)	$	80.418	$	74.063	$	6.355
Crude oil product margin ($/barrel) (3)	$	4.854	$	4.278	$	0.576

(1)    Revenues include $1.7 million and $2.5 million of intersegment sales during the three months ended December 31, 2022 and 2021, respectively, that are eliminated in our unaudited condensed consolidated statements of operations.

(2)    Information is presented as of December 31, 2022 and December 31, 2021, respectively. The decrease in crude oil inventory was due primarily to capitalizing additional crude oil barrels as linefill as a result of increased requirements.

(3)    Cost and product margin per barrel excludes the impact of derivatives.

Crude Oil Sales Revenues. The decrease was due primarily to a reduction in sales volumes primarily due to lower production in the DJ Basin and increased buy/sell transactions during the quarter ended December 31, 2022. Buy/sell transactions are transactions in which we purchase product from a counterparty and sell the same volumes of product to the same counterparty at a different location or time. The revenues, cost of sales and volumes are netted for these transactions. The decrease was partially offset by an increase in crude oil prices during the three months ended December 31, 2022, compared to the three months ended December 31, 2021

Crude Oil Transportation and Other Revenues. The increase was primarily due to an increase in charter days and day rates within our marine transportation business due to increased demand.

During the three months ended December 31, 2022, physical volumes on the Grand Mesa Pipeline averaged approximately 77,000 barrels per day, compared to approximately 83,000 barrels per day for the three months ended December 31, 2021 (volume amounts are from both internal and external parties). Both contracted and non-contracted volumes decreased as overall production in the DJ Basin declined in part due to producer permitting issues.

Cost of Sales-Excluding Impact of Derivatives. The decrease was due primarily to a reduction in sales volumes, as discussed above, which was partially offset by an increase in crude oil prices.

Derivative (Gain) Loss. Our cost of sales during the three months ended December 31, 2022 included $3.5 million of net realized gains on derivatives, driven by decreasing crude oil prices, and $1.8 million of net unrealized gains on derivatives. The amount for the three months ended December 31, 2022 includes net realized gains of $10.1 million and net unrealized

36

losses of $0.7 million associated with derivative instruments related to our hedge of the CMA Differential Roll, defined and discussed below under “Non-GAAP Financial Measures.” Our cost of sales during the three months ended December 31, 2021 included $34.7 million of net realized losses on derivatives, driven by the increase in crude oil prices, and $32.2 million of net unrealized gains on derivatives. The amount for the three months ended December 31, 2021 includes net realized losses of $25.5 million and net unrealized gains of $26.4 million associated with derivative instruments related to our hedge of the CMA Differential Roll.

Crude Oil Product Margin. The increase was due to higher crude oil prices due to higher contracted rates with certain producers as well as increased differentials on certain other sales contracts. Crude oil product margin calculations do not include gains and losses from derivatives that may offset the movement in the physical margin.

Operating and General and Administrative Expenses. The decrease was primarily related to the sale of the trucking business during the three months ended March 31, 2022.

Depreciation and Amortization Expense. The decrease was due primarily to the sale of our trucking assets during the three months ended March 31, 2022.

Loss on Disposal or Impairment of Assets, Net. During the three months ended December 31, 2022, we recorded a net loss of $0.3 million primarily due to disposals and retirements of certain assets. During the three months ended December 31, 2021, we recorded a net loss of $2.2 million for an impairment due to damage caused by Hurricane Ida to one of our Gulf Coast terminals.

37

Liquids Logistics

The following table summarizes the operating results of our Liquids Logistics segment for the periods indicated:

	Three Months Ended December 31,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Refined products sales:
Revenues-excluding impact of derivatives	$	609,686	$	503,383	$	106,303
Cost of sales-excluding impact of derivatives	593,704		493,388		100,316
Derivative loss	1,023		189		834
Product margin	14,959		9,806		5,153
Propane sales:
Revenues	332,328		397,365		(65,037)
Cost of sales-excluding impact of derivatives	313,151		403,814		(90,663)
Derivative loss (gain)	7,486		(1,392)		8,878
Product margin (loss)	11,691		(5,057)		16,748
Butane sales:
Revenues	241,805		296,844		(55,039)
Cost of sales-excluding impact of derivatives	237,478		272,450		(34,972)
Derivative gain	(3,628)		(5,959)		2,331
Product margin	7,955		30,353		(22,398)
Other product sales:
Revenues-excluding impact of derivatives	231,650		228,541		3,109
Cost of sales-excluding impact of derivatives	225,480		213,654		11,826
Derivative loss	1,189		6,816		(5,627)
Product margin	4,981		8,071		(3,090)
Service revenues:
Revenues	2,310		2,280		30
Cost of sales	454		193		261
Product margin	1,856		2,087		(231)
Expenses:
Operating expenses	15,247		16,551		(1,304)
General and administrative expenses	2,266		1,821		445
Depreciation and amortization expense	3,417		3,756		(339)
Gain on disposal or impairment of assets, net	(1)		(26)		25
Total expenses	20,929		22,102		(1,173)
Segment operating income	$	20,513	$	23,158	$	(2,645)

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	Three Months Ended December 31,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Natural gas liquids and refined products storage capacity - owned and leased (gallons) (1)	159,999		168,189		(8,190)
Refined products sold (gallons)	192,340		203,898		(11,558)
Refined products sold ($/gallon)	$	3.170	$	2.469	$	0.701
Cost per refined products sold ($/gallon) (2)	$	3.087	$	2.420	$	0.667
Refined products product margin ($/gallon) (2)	$	0.083	$	0.049	$	0.034
Refined products inventory (gallons) (1 )	1,738		1,314		424
Propane sold (gallons)	305,067		294,282		10,785
Propane sold ($/gallon)	$	1.089	$	1.350	$	(0.261)
Cost per propane sold ($/gallon) (2)	$	1.026	$	1.372	$	(0.346)
Propane product margin (loss) ($/gallon) (2)	$	0.063	$	(0.022)	$	0.085
Propane inventory (gallons) (1)	97,283		125,235		(27,952)
Butane sold (gallons)	177,061		180,191		(3,130)
Butane sold ($/gallon)	$	1.366	$	1.647	$	(0.281)
Cost per butane sold ($/gallon) (2)	$	1.341	$	1.512	$	(0.171)
Butane product margin ($/gallon) (2)	$	0.025	$	0.135	$	(0.110)
Butane inventory (gallons) (1)	31,029		45,129		(14,100)
Other products sold (gallons)	96,349		99,915		(3,566)
Other products sold ($/gallon)	$	2.404	$	2.287	$	0.117
Cost per other products sold ($/gallon) (2)	$	2.340	$	2.138	$	0.202
Other products product margin ($/gallon) (2)	$	0.064	$	0.149	$	(0.085)
Other products inventory (gallons) (1)	13,360		23,491		(10,131)

(1)    Information is presented as of December 31, 2022 and December 31, 2021, respectively.

(2)    Cost and product margin per gallon excludes the impact of derivatives.

Refined Products Revenues and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales, excluding the impact of derivatives, were due to an increase in refined products prices. This was partially offset by a decrease in volumes primarily related to tighter supply in certain markets.

Refined Products Derivative Loss. Our refined products margin during the three months ended December 31, 2022 included a realized loss of $1.0 million and the three months ended December 31, 2021 included a realized loss of $0.2 million.

Refined Products product margins increased during the three months ended December 31, 2022 due to continued higher demand in several markets that were experiencing tighter supply as well as being positioned from a supply and inventory perspective during the continued period of extreme volatility in commodity prices.

Propane Sales and Cost of Sales-Excluding Impact of Derivatives. The decreases in revenues and cost of sales were due to significantly lower propane market prices during the three months ended December 31, 2022 compared to the three months ended December 31, 2021. Propane prices have declined along with the decline in global energy prices as a result of the increase in interest rates to curb inflation and the overall concerns in the economy about a potential recession, as well as due to an increase in days of domestic supply available, combined with lower forecasted demand. Sales volumes increased as customers started taking delivery of their forward fixed-priced sales contracts. This was partially offset by sales volumes decreases due to the decommissioning of a critical underground storage facility in the Midwest in April 2022. We expect the volume previously sold at this facility will be partially replaced by redirecting customers to other facilities and by transloading product from railcars to trucks.

Propane Derivative Loss (Gain). Our wholesale cost of propane sales during the three months ended December 31, 2022 included net unrealized gains of $1.2 million on derivatives and $8.7 million of net realized losses on derivatives. During the three months ended December 31, 2021, our wholesale cost of propane sales included $29.7 million of net unrealized losses on derivatives and $31.1 million of net realized gains on derivatives.

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Propane product margins, excluding the impact of derivatives, increased as our current inventory value has reduced with purchases in a lower price environment and the margins from forward fixed-priced sales contracts which were delivered to our customers during the three months ended December 31, 2022. During the three months ended December 31, 2021, we experienced the opposite situation and were replacing our inventory when prices were rising.

Butane Sales and Cost of Sales-Excluding Impact of Derivatives. The decreases in revenues and cost of sales were due to lower prices and weaker spot demand for the product, especially exports. The softening of export economics continued during the three months ended December 31, 2022, which led to lower domestic prices as less product was being moved abroad. Overall concerns about the economy and inflation also continued to weigh on the domestic market. The decline in volumes was primarily due to the export market as we were able to supply more product in the prior year to export companies.

Butane Derivative Gain. Our cost of butane sales during the three months ended December 31, 2022 included $9.1 million of net unrealized losses on derivatives and $12.8 million of net realized gains on derivatives. Our cost of butane sales included $12.9 million of net unrealized gains on derivatives and $6.9 million of net realized losses on derivatives during the three months ended December 31, 2021.

Butane product margins, excluding the impact of derivatives, decreased during the three months ended December 31, 2022, as compared to the three months ended December 31, 2021 due to the declining prices, lower export demand and increased freight charges due to higher fuel surcharges.

Other Products Sales and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales, excluding the impact of derivatives, were due to our increased supply of biodiesel to sell during the three months ended December 31, 2022 as compared to the three months ended December 31, 2021 due to favorable supply contracts entered into in the prior year. This was partially offset by a decrease in asphalt revenues as we were impacted by supply constraints during the first two months of the quarter.

Other Products Derivative Loss. Our derivatives of other products included $1.3 million of net unrealized gains and $2.5 million of net realized losses on derivatives during the three months ended December 31, 2022. Our derivatives of other products during the three months ended December 31, 2021 included $0.1 million of net unrealized losses and $6.7 million of net realized losses on derivatives.

Other product sales product margins during the three months ended December 31, 2022 decreased from the prior year primarily due to a decrease in feedstock prices, which drove a decrease in the index price of biodiesel. The decrease in feedstock prices was largely driven by the Environmental Protection Agency’s finalization of its renewables volume obligation requirements for biodiesel producers for future periods, which was announced in December 2022. Also, asphalt margins declined as we had supply constraints in October and November 2022.

Service Revenues. This revenue includes storage, terminaling and transportation services income. Revenues during the three months ended December 31, 2022 were consistent with the three months ended December 31, 2021.

Operating and General and Administrative Expenses. The decrease was primarily related to lower incentive compensation costs due to lower operating results.

Depreciation and Amortization Expense. The decrease was primarily due to lower amortization expense due to certain intangible assets being fully amortized as of December 31, 2021.

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Corporate and Other

The operating loss within “Corporate and Other” includes the following components for the periods indicated:

	Three Months Ended December 31,
	2022		2021		Change
	(in thousands)
Expenses:
General and administrative expenses	$	10,934	$	13,447	$	(2,513)
Depreciation and amortization expense	1,655		1,743		(88)
Loss on disposal or impairment of assets, net	71		—		71
Total expenses	12,660		15,190		(2,530)
Operating loss	$	(12,660)	$	(15,190)	$	2,530

General and Administrative Expenses. The expenses during the three months ended December 31, 2022 were lower due to lower compensation expense as a result of lower headcount and lower consulting fees.

Depreciation and Amortization Expense. Depreciation and amortization expense during the three months ended December 31, 2022 was consistent with the three months ended December 31, 2021.

Loss on Disposal or Impairment of Assets, Net. During the three months ended December 31, 2022, we recorded an impairment loss on the sublease of a building we were no longer using.

Equity in Earnings of Unconsolidated Entities

Equity in earnings of unconsolidated entities was $1.2 million during the three months ended December 31, 2022, compared to $0.1 million during the three months ended December 31, 2021. The increase of $1.1 million during the three months ended December 31, 2022 was due primarily to higher earnings from certain membership interests related to specific land and water services operations and a lower loss from our interest in an aircraft company.

Interest Expense

The following table summarizes the components of our consolidated interest expense for the periods indicated:

	Three Months Ended December 31,
	2022		2021		Change
	(in thousands)
Senior secured notes	$	38,438	$	38,438	$	—
Senior unsecured notes	18,925		21,797		(2,872)
Revolving credit facility	5,244		2,955		2,289
Other indebtedness	9,152		867		8,285
Total debt interest expense	71,759		64,057		7,702
Amortization of debt issuance costs	4,161		4,322		(161)
Total interest expense	$	75,920	$	68,379	$	7,541

The debt interest expense increased $7.7 million during the three months ended December 31, 2022 due primarily to the accrual of a settlement of a claim for the failure to pay interest on royalty payments, as discussed further in Note 7 to our unaudited condensed consolidated financial statements included in this Quarterly Report. This increase was also due in part to an increase in the average balance outstanding under our revolving credit facility in the current period compared to the same period in the prior year and increased floating interest rates, offset by lower interest expense resulting from repurchases of a portion of our Senior Unsecured Notes.

Gain on Early Extinguishment of Liabilities, Net

Gain on early extinguishment of liabilities, net was $2.7 million during the three months ended December 31, 2022, compared to less than $0.1 million during the three months ended December 31, 2021. During the three months ended December 31, 2022 and 2021, the net gain (inclusive of debt issuance costs written off) relates to the early extinguishment of a

41

portion of the outstanding Senior Unsecured Notes (as defined herein). See Note 6 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Other Income, Net

The increase in other income, net for the three months ended December 31, 2022, compared to the three months ended December 31, 2021, was due primarily to the settlement of a dispute associated with commercial activities not occurring in the current reporting periods. See Note 15 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Income Tax Benefit

Income tax benefit was $0.3 million during the three months ended December 31, 2022, compared to an income tax benefit of $0.1 million during the three months ended December 31, 2021. See Note 2 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Noncontrolling Interests

Noncontrolling interests represent the portion of certain consolidated subsidiaries that are owned by third-parties. Noncontrolling interest income was $0.4 million during the three months ended December 31, 2022, compared to a noncontrolling interest loss of $0.1 million during the three months ended December 31, 2021. The increase during the three months ended December 31, 2022 was due primarily to higher income from certain water solutions operations.

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Segment Operating Results for the Nine Months Ended December 31, 2022 and 2021

Water Solutions

The following table summarizes the operating results of our Water Solutions segment for the periods indicated:

	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands, except per barrel and per day amounts)
Revenues:
Water disposal service fees	$	373,851	$	293,291	$	80,560
Sale of recovered crude oil	96,205		48,848		47,357
Recycled water	12,842		7,207		5,635
Other revenues	28,333		47,743		(19,410)
Total revenues	511,231		397,089		114,142
Expenses:
Cost of sales-excluding impact of derivatives	9,316		20,892		(11,576)
Derivative loss	4,363		899		3,464
Operating expenses	158,401		125,667		32,734
General and administrative expenses	6,996		5,509		1,487
Depreciation and amortization expense	153,766		164,466		(10,700)
Loss on disposal or impairment of assets, net	17,935		19,450		(1,515)
Total expenses	350,777		336,883		13,894
Segment operating income	$	160,454	$	60,206	$	100,248
Produced water processed (barrels per day)
Delaware Basin	2,001,242		1,488,529		512,713
Eagle Ford Basin	114,191		99,298		14,893
DJ Basin	151,792		142,606		9,186
Other Basins	15,114		25,516		(10,402)
Total	2,282,339		1,755,949		526,390
Recycled water (barrels per day)	132,851		76,319		56,532
Total (barrels per day)	2,415,190		1,832,268		582,922
Skim oil sold (barrels per day)	3,757		2,667		1,090
Service fees for produced water processed ($/barrel) (1)	$	0.60	$	0.61	$	(0.01)
Recovered crude oil for produced water processed ($/barrel) (1)	$	0.15	$	0.10	$	0.05
Operating expenses for produced water processed ($/barrel) (1)	$	0.25	$	0.26	$	(0.01)

(1)    Total produced water barrels processed during the nine months ended December 31, 2022 and 2021 were 627,643,232 and 482,885,902, respectively.

Water Disposal Service Fee Revenues. The increase was due to an increase in produced water volumes processed as a result of increased crude oil production driven by higher crude oil prices and completion activity, primarily in the Delaware Basin. This was partially offset by lower service fees received per barrel due to increased volumes from customers with long-term acreage dedications or minimum volume commitments with lower contracted fees.

Recovered Crude Oil Revenues. The increase was due primarily to higher volumes of skim oil barrels sold due to an increase in produced water volumes processed as well as higher realized crude oil prices received from the sale of skim oil barrels. Additionally, an increase in the number of wells completed in our area of operations during the period with increased flowback activity resulted in higher skim oil volumes per barrel of produced water processed

Recycled Water Revenues. The increase was due primarily to increasing demand for water to be used in completions, driven by an increase in drilling and completion activity primarily in the Delaware Basin, and our customers’ transition from brackish non-potable water to recycled water and higher pricing for recycled water.

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Other Revenues. The decrease was due primarily to lower sales of brackish non-potable water related to the termination of a joint marketing agreement as well as our customers transitioning from brackish non-potable water to recycled water, partially offset by reimbursements for construction projects in the current period.

Cost of Sales-Excluding Impact of Derivatives. The decrease was due primarily to lower purchases of brackish non-potable water from third-parties to meet customer needs due to the termination of a joint marketing agreement.

Derivative Loss. During the nine months ended December 31, 2022, we had $4.5 million of net unrealized gains on derivatives and $8.8 million of net realized losses on derivatives. During the nine months ended December 31, 2021, we had $6.8 million of net unrealized losses on derivatives and $5.9 million of net realized gains on derivatives.

Operating and General and Administrative Expenses. The increase was due primarily to higher utility, royalty and chemical expenses as a result of the increase in produced water volumes processed. Utility, royalty and chemical expenses, which are three of our largest variable expenses, were not impacted by the rise in inflation due to negotiated long-term utility contracts with fixed rates, royalty contracts with no escalation clauses and a fixed chemical expense per barrel with our chemical provider. The increase was also due to higher repairs and maintenance expense due to timing of repairs and the operation of temporary booster stations, higher incentive compensation expense and higher severance taxes due to the increase in revenue from recovered crude oil.

Depreciation and Amortization Expense. The decrease was due primarily to certain long-term assets being fully amortized or impaired during the fiscal year ended March 31, 2022 and nine months ended December 31, 2022. This decrease was partially offset by the depreciation of newly developed facilities and infrastructure.

Loss on Disposal or Impairment of Assets, Net. During the nine months ended December 31, 2022, we recorded a net loss of $11.8 million to write down the value of two inactive saltwater disposal facilities and damaged equipment at another saltwater disposal facility, as well as the abandonment of certain capital projects and the retirement of certain assets. We also recorded a net loss of $8.0 million primarily related to the sale of certain assets and a loss of $0.5 million related to the termination of a joint marketing agreement. In addition, we recorded a gain of $2.2 million from an insurance recovery for a saltwater disposal facility damaged in a prior period. During the nine months ended December 31, 2021, we recorded a net loss of $23.7 million primarily related to the write-down of an inactive saltwater disposal facility and damaged equipment and wells at other facilities, abandonment of certain capital projects and the sale of certain other miscellaneous assets and a gain of $4.3 million on the sale of certain land and a landfill permit.

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Crude Oil Logistics

The following table summarizes the operating results of our Crude Oil Logistics segment for the periods indicated:

	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands, except per barrel amounts)
Revenues:
Crude oil sales	$	1,906,963	$	1,660,225	$	246,738
Crude oil transportation and other	72,645		62,606		10,039
Total revenues (1)	1,979,608		1,722,831		256,777
Expenses:
Cost of sales-excluding impact of derivatives	1,823,514		1,557,202		266,312
Derivative (gain) loss	(7,213)		41,849		(49,062)
Operating expenses	38,563		40,862		(2,299)
General and administrative expenses	3,818		5,742		(1,924)
Depreciation and amortization expense	35,193		37,029		(1,836)
(Gain) loss on disposal or impairment of assets, net	(1,279)		2,206		(3,485)
Total expenses	1,892,596		1,684,890		207,706
Segment operating income	$	87,012	$	37,941	$	49,071
Crude oil sold (barrels)	19,428		23,027		(3,599)
Crude oil transported on owned pipelines (barrels)	20,832		21,961		(1,129)
Crude oil storage capacity - owned and leased (barrels) (2)	5,232		5,232		—
Crude oil storage capacity leased to third-parties (barrels) (2)	2,000		1,501		499
Crude oil inventory (barrels) (2)	892		1,295		(403)
Crude oil sold ($/barrel)	$	98.155	$	72.099	$	26.056
Cost per crude oil sold ($/barrel) (3)	$	93.860	$	67.625	$	26.235
Crude oil product margin ($/barrel) (3)	$	4.295	$	4.474	$	(0.179)

(1)    Revenues include $7.8 million and $7.2 million of intersegment sales during the nine months ended December 31, 2022 and 2021, respectively, that are eliminated in our unaudited condensed consolidated statements of operations.

(2)    Information is presented as of December 31, 2022 and December 31, 2021, respectively. The decrease in crude oil inventory was due primarily to capitalizing additional crude oil barrels as linefill as a result of increased requirements.

(3)    Cost and product margin per barrel excludes the impact of derivatives.

Crude Oil Sales Revenues. The increase was due primarily to an increase in crude oil prices during the nine months ended December 31, 2022, compared to the nine months ended December 31, 2021. This was partially offset by a reduction in sales volumes primarily due to lower production in the DJ Basin and increased buy/sell transactions during the nine months ended December 31, 2022.

Crude Oil Transportation and Other Revenues. The increase was primarily due to an increase in charter days and day rates within our marine transportation business due to increased demand.

During the nine months ended December 31, 2022, physical volumes on the Grand Mesa Pipeline averaged approximately 76,000 barrels per day, compared to approximately 80,000 barrels per day for the nine months ended December 31, 2021 (volume amounts are from both internal and external parties). Both contracted and non-contracted volumes decreased as overall production in the DJ Basin declined in part due to producer permitting issues.

Cost of Sales-Excluding Impact of Derivatives. The increase was due primarily to an increase in crude oil prices during the nine months ended December 31, 2022, compared to the nine months ended December 31, 2021.

Derivative (Gain) Loss. Our cost of sales during the nine months ended December 31, 2022 included $50.2 million of net realized losses on derivatives, driven by increasing crude oil prices, and $57.4 million of net unrealized gains on derivatives. The amount for the nine months ended December 31, 2022 includes net realized losses of $27.4 million and net unrealized gains of $35.3 million associated with derivative instruments related to our hedge of the CMA Differential Roll defined and discussed below under “Non-GAAP Financial Measures.” Our cost of sales during the nine months ended December 31, 2021

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included $95.7 million of net realized losses on derivatives, driven by the increase in crude oil prices, and $53.8 million of net unrealized gains on derivatives. The amount for the nine months ended December 31, 2021 includes net realized losses of $65.7 million and net unrealized gains of $54.3 million associated with derivative instruments related to our hedge of the CMA Differential Roll.

Crude Oil Product Margin. The decrease in product margin was primarily due to the sale of higher priced inventory into a market in which prices were declining during the first six months of the current period. In the prior year, lower priced inventory was sold into a market in which prices were rising during the first six months of the prior year period. In addition, we incurred increased freight costs during the current period. This decrease in product margin was offset by higher contracted rates with certain producers as well as increased differentials on certain other sales contracts in the last three months of the period. Crude oil product margin calculations do not include gains and losses from derivatives that may offset the movement in the physical margin.

Operating and General and Administrative Expenses. The decrease was primarily related to the sale of the trucking business during the three months ended March 31, 2022, and the completion of the renegotiation of certain leases that resulted in a reduction to expense during the current period.

Depreciation and Amortization Expense. The decrease was due primarily to the sale of our trucking assets during the three months ended March 31, 2022.

(Gain) Loss on Disposal or Impairment of Assets, Net. During the nine months ended December 31, 2022, we recorded a net gain of $1.3 million primarily due to disposals and retirements of certain assets. During the nine months ended December 31, 2021, we recorded a net loss of $2.2 million for an impairment due to damage caused by Hurricane Ida to one of our Gulf Coast terminals.

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Liquids Logistics

The following table summarizes the operating results of our Liquids Logistics segment for the periods indicated:

	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Refined products sales:
Revenues-excluding impact of derivatives (1)	$	1,994,123	$	1,340,824	$	653,299
Cost of sales-excluding impact of derivatives	1,960,944		1,324,587		636,357
Derivative loss	1,596		1,309		287
Product margin	31,583		14,928		16,655
Propane sales:
Revenues (1)	754,438		778,308		(23,870)
Cost of sales-excluding impact of derivatives	723,486		771,116		(47,630)
Derivative loss (gain)	18,304		(26,221)		44,525
Product margin	12,648		33,413		(20,765)
Butane sales:
Revenues (1)	594,612		583,080		11,532
Cost of sales-excluding impact of derivatives	597,181		540,607		56,574
Derivative (gain) loss	(22,551)		15,554		(38,105)
Product margin	19,982		26,919		(6,937)
Other product sales:
Revenues-excluding impact of derivatives (1)	812,398		570,878		241,520
Cost of sales-excluding impact of derivatives	761,761		535,203		226,558
Derivative loss	19,380		9,484		9,896
Product margin	31,257		26,191		5,066
Service revenues:
Revenues (1)	11,394		14,583		(3,189)
Cost of sales	1,152		1,151		1
Product margin	10,242		13,432		(3,190)
Expenses:
Operating expenses	40,407		41,081		(674)
General and administrative expenses	6,254		5,376		878
Depreciation and amortization expense	10,194		15,409		(5,215)
Loss on disposal or impairment of assets, net	51		71,807		(71,756)
Total expenses	56,906		133,673		(76,767)
Segment operating income (loss)	$	48,806	$	(18,790)	$	67,596

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	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Natural gas liquids and refined products storage capacity - owned and leased (gallons) (2)	159,999		168,189		(8,190)
Refined products sold (gallons)	566,997		586,136		(19,139)
Refined products sold ($/gallon)	$	3.517	$	2.288	$	1.229
Cost per refined products sold ($/gallon) (3)	$	3.458	$	2.260	$	1.198
Refined products product margin ($/gallon) (3)	$	0.059	$	0.028	$	0.031
Refined products inventory (gallons) (2)	1,738		1,314		424
Propane sold (gallons)	639,686		644,883		(5,197)
Propane sold ($/gallon)	$	1.179	$	1.207	$	(0.028)
Cost per propane sold ($/gallon) (3)	$	1.131	$	1.196	$	(0.065)
Propane product margin ($/gallon) (3)	$	0.048	$	0.011	$	0.037
Propane inventory (gallons) (2)	97,283		125,235		(27,952)
Butane sold (gallons)	409,137		427,646		(18,509)
Butane sold ($/gallon)	$	1.453	$	1.363	$	0.090
Cost per butane sold ($/gallon) (3)	$	1.460	$	1.264	$	0.196
Butane product (loss) margin ($/gallon) (3)	$	(0.007)	$	0.099	$	(0.106)
Butane inventory (gallons) (2)	31,029		45,129		(14,100)
Other products sold (gallons)	294,965		290,078		4,887
Other products sold ($/gallon)	$	2.754	$	1.968	$	0.786
Cost per other products sold ($/gallon) (3)	$	2.583	$	1.845	$	0.738
Other products product margin ($/gallon) (3)	$	0.171	$	0.123	$	0.048
Other products inventory (gallons) (2)	13,360		23,491		(10,131)

(1)    Revenue includes $1.3 million of intersegment sales during the nine months ended December 31, 2021 that is eliminated in our unaudited condensed consolidated statement of operations.

(2)    Information is presented as of December 31, 2022 and December 31, 2021, respectively.

(3)    Cost and product margin per gallon excludes the impact of derivatives.

Refined Products Revenues and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales, excluding the impact of derivatives, were due to an increase in refined products prices. This was partially offset by a decrease in volumes primarily related to tighter supply in certain markets.

Refined Products Derivative Loss. Our refined products margin during the nine months ended December 31, 2022 included a realized loss of $1.6 million and the nine months ended December 31, 2021 included a realized loss of $1.3 million.

Refined Products product margins for the nine months ended December 31, 2022 increased from the nine months ended December 31, 2021 due to higher demand in several markets that were experiencing tighter supply as well as being well positioned from a supply and inventory perspective during the continued period of extreme volatility in commodity prices.

Propane Sales and Cost of Sales-Excluding Impact of Derivatives. The decreases in revenues and cost of sales were due to lower propane prices. Propane prices have declined along with the decline in global energy prices as a result of the increase in interest rates to curb inflation and the overall concerns in the economy about a potential recession, as well as due to an increase in days of domestic supply available, combined with lower forecasted demand. Sales volumes decreased due to the decommissioning of a critical underground storage facility in the Midwest in April 2022.

Propane Derivative Loss (Gain). Our wholesale propane cost of sales included $10.7 million of net unrealized losses on derivatives and $7.6 million of net realized losses on derivatives during the nine months ended December 31, 2022. During the nine months ended December 31, 2021, our cost of wholesale propane sales included $4.0 million of net unrealized gains on derivatives and $22.3 million of net realized gains on derivatives.

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Propane product margins, excluding the impact of derivatives, increased as we replaced our inventory in a lower price environment and we realized the margin associated with our forward fixed-priced sales contracts and lower inventory costs due to the decreasing prices throughout the nine months ended December 31, 2022. During the nine months ended December 31, 2021, we experienced the opposite situation and were replacing our inventory when prices were rising.

Butane Sales and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales were due primarily to higher butane prices which were offset by lower volumes due to export economics beginning to soften during the three months ended June 30, 2022, which led to lower domestic prices as less product was being moved abroad. Prices also declined during the three months ended September 30, 2022 due to overall concerns about the economy and inflation weighing on the domestic market.

Butane Derivative (Gain) Loss. Our cost of butane sales during the nine months ended December 31, 2022 included $5.7 million of net unrealized gains on derivatives and $16.9 million of net realized gains on derivatives. Our cost of butane sales included $2.6 million of net unrealized losses on derivatives and $12.9 million of net realized losses on derivatives during the nine months ended December 31, 2021.

Butane product margins, excluding the impact of derivatives, decreased during the nine months ended December 31, 2022, as compared to the nine months ended December 31, 2021 due to the declining prices, lower export demand and increased freight charges due to higher fuel surcharges. In addition, we were also negatively impacted by lower location differentials as the product we contracted to purchase in the beginning of the season was continuing to compete with product purchased in the discounted market.

Other Products Sales and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales, excluding the impact of derivatives, were due to higher commodity prices and an increased supply of biodiesel to sell during the current year compared to the prior year period due to favorable supply contracts entered into in the prior year.

Other Products Derivatives Loss. Our derivatives of other products included $0.1 million of net unrealized gains on derivatives and $19.5 million of net realized losses on derivatives during the nine months ended December 31, 2022. Our derivatives of other products during the nine months ended December 31, 2021 included less than $0.1 million of net unrealized losses on derivatives and $9.5 million of net realized losses on derivatives.

Other product sales product margins during the nine months ended December 31, 2022 increased due to an increase in biodiesel and biodiesel renewable identification number market prices, as well as securing favorable biodiesel supply contracts in the Midwest and transporting the product for sale in more favorable markets.

Service Revenues. This revenue includes storage, terminaling and transportation services income. The decrease during the nine months ended December 31, 2022 was due to the disposition of Sawtooth in June 2021 as well as less throughput in certain of our propane and butane terminals.

Operating and General and Administrative Expenses. The increase was primarily due to an increase in travel and entertainment, materials and supplies and repair and maintenance expenses partially offset by the sale of Sawtooth in June 2021.

Depreciation and Amortization Expense. The decrease was primarily due to the disposition of Sawtooth in June 2021 as well as lower amortization expense due to certain intangible assets being fully amortized as of December 31, 2022.

Loss on Disposal or Impairment of Assets, Net. During the nine months ended December 31, 2022, we recorded a net loss of $0.1 million primarily due to disposals of certain assets. During the nine months ended December 31, 2021, we recorded a net loss of $60.1 million related to the sale of Sawtooth and a net loss of $11.8 million related to the sale of another terminal during the three months ended September 30, 2021.

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Corporate and Other

The operating loss within “Corporate and Other” includes the following components for the periods indicated:

	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands)
Expenses:
General and administrative expenses	$	33,533	$	29,522	$	4,011
Depreciation and amortization expense	4,952		5,241		(289)
Gain on disposal or impairment of assets, net	(916)		—		(916)
Total expenses	37,569		34,763		2,806
Operating loss	$	(37,569)	$	(34,763)	$	(2,806)

General and Administrative Expenses. The expenses during the nine months ended December 31, 2022 were higher than the nine months ended December 31, 2021 due to increased incentive compensation expense compared to the prior year. Equity-based compensation also increased primarily due to a reversal of an incentive compensation accrual during the nine months ended December 31, 2021.

Depreciation and Amortization Expense. Depreciation and amortization expense during the nine months ended December 31, 2022 was consistent with the nine months ended December 31, 2021.

Gain on Disposal or Impairment of Assets, Net. During the nine months ended December 31, 2022, we sold an airplane for a gain of $1.3 million, which was partially offset by a loss recorded to write-off the remaining amount of a loan receivable, due July 31, 2023, that was prepaid by the debtor (as discussed further in Note 2 to our unaudited condensed consolidated financial statements included in this Quarterly Report) and an impairment loss recorded on the sublease of a building we were no longer using.

Equity in Earnings of Unconsolidated Entities

Equity in earnings of unconsolidated entities was $3.1 million during the nine months ended December 31, 2022, compared to $0.8 million during the nine months ended December 31, 2021. The increase of $2.3 million during the nine months ended December 31, 2022 was due primarily to higher earnings from certain membership interests related to specific land and water services operations and a lower loss from our interest in an aircraft company.

Interest Expense

The following table summarizes the components of our consolidated interest expense for the periods indicated:

	Nine Months Ended December 31,
	2022		2021		Change
	(in thousands)
Senior secured notes	$	115,313	$	115,313	$	—
Senior unsecured notes	60,028		66,471		(6,443)
Revolving credit facility	13,146		7,201		5,945
Other indebtedness	10,508		2,205		8,303
Total debt interest expense	198,995		191,190		7,805
Amortization of debt issuance costs	12,533		12,814		(281)
Total interest expense	$	211,528	$	204,004	$	7,524

The debt interest expense increased $7.8 million during the nine months ended December 31, 2022 due primarily to the accrual of a settlement of a claim for the failure to pay interest on royalty payments, as discussed further in Note 7 to our unaudited condensed consolidated financial statements included in this Quarterly Report. This increase was also due in part to an increase in the average balance outstanding under our revolving credit facility in the current period compared to the same period in the prior year and increased floating interest rates, offset by lower interest expense resulting from repurchases of a portion of our Senior Unsecured Notes.

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Gain on Early Extinguishment of Liabilities, Net

Gain on early extinguishment of liabilities, net was $6.8 million during the nine months ended December 31, 2022, compared to $1.1 million during the nine months ended December 31, 2021. During the nine months ended December 31, 2022 and 2021, the net gain (inclusive of debt issuance costs written off) primarily relates to the early extinguishment of a portion of the outstanding Senior Unsecured Notes (as defined herein). For the nine months ended December 31, 2021, the net gain was partially offset by a loss on the early extinguishment of the Sawtooth credit agreement. See Note 6 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Other Income, Net

The increase in other income, net for the nine months ended December 31, 2022, compared to the nine months ended December 31, 2021, was due primarily to the settlement of a dispute associated with commercial activities not occurring in the current reporting periods. See Note 15 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Income Tax (Expense) Benefit

Income tax expense was $0.1 million during the nine months ended December 31, 2022, compared to an income tax benefit of $0.8 million during the nine months ended December 31, 2021. See Note 2 to our unaudited condensed consolidated financial statements included in this Quarterly Report for a further discussion.

Noncontrolling Interests

Noncontrolling interest income was $0.8 million during the nine months ended December 31, 2022, compared to $0.7 million during the nine months ended December 31, 2021. The increase during the nine months ended December 31, 2022 was due primarily to higher income from certain water solutions operations during the nine months ended December 31, 2022 and a loss of $0.2 million from the operations of Sawtooth during the nine months ended December 31, 2021, partially offset by lower income from certain recycling operations during the nine months ended December 31, 2022.

Non-GAAP Financial Measures

In addition to financial results reported in accordance with accounting principles generally accepted in the United States (“GAAP”), we have provided the non-GAAP financial measures of EBITDA and Adjusted EBITDA. These non-GAAP financial measures are not intended to be a substitute for those reported in accordance with GAAP. These measures may be different from non-GAAP financial measures used by other entities, even when similar terms are used to identify such measures.

We define EBITDA as net income (loss) attributable to NGL Energy Partners LP, plus interest expense, income tax expense (benefit), and depreciation and amortization expense. We define Adjusted EBITDA as EBITDA excluding net unrealized gains and losses on derivatives, lower of cost or net realizable value adjustments, gains and losses on disposal or impairment of assets, gains and losses on early extinguishment of liabilities, equity-based compensation expense, acquisition expense, revaluation of liabilities, certain legal settlements and other. We also include in Adjusted EBITDA certain inventory valuation adjustments related to certain refined products businesses within our Liquids Logistics segment as discussed below. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income (loss), income (loss) before income taxes, cash flows from operating activities, or any other measure of financial performance calculated in accordance with GAAP, as those items are used to measure operating performance, liquidity or the ability to service debt obligations. We believe that EBITDA provides additional information to investors for evaluating our ability to make quarterly distributions to our unitholders and is presented solely as a supplemental measure. We believe that Adjusted EBITDA provides additional information to investors for evaluating our financial performance without regard to our financing methods, capital structure and historical cost basis. Further, EBITDA and Adjusted EBITDA, as we define them, may not be comparable to EBITDA, Adjusted EBITDA, or similarly titled measures used by other entities.

Other than for certain businesses within our Liquids Logistics segment, for purposes of our Adjusted EBITDA calculation, we make a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is open, we record changes in the fair value of the derivative as an unrealized gain or loss. When a derivative contract matures or is settled, we reverse the previously recorded unrealized gain or loss and record a realized gain or loss. We do not draw such a distinction between realized and unrealized gains and losses on derivatives of certain businesses within our Liquids Logistics segment. The primary hedging strategy of these businesses is to hedge against the risk of declines in the value

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of inventory over the course of the contract cycle, and many of the hedges cover extended periods of time. The “inventory valuation adjustment” row in the reconciliation table reflects the difference between the market value of the inventory of these businesses at the balance sheet date and its cost. We include this in Adjusted EBITDA because the unrealized gains and losses associated with derivative contracts associated with the inventory of this segment, which are intended primarily to hedge inventory holding risk and are included in net income, also affect Adjusted EBITDA. In our Crude Oil Logistics segment, we purchase certain crude oil barrels using the West Texas Intermediate (“WTI”) calendar month average (“CMA”) price and sell the crude oil barrels using the WTI CMA price plus the Argus CMA Differential Roll Component (“CMA Differential Roll”) per our contracts. To eliminate the volatility of the CMA Differential Roll, we entered into derivative instrument positions in January 2021 to secure a margin of approximately $0.20 per barrel on 1.5 million barrels per month from May 2021 through December 2023. Due to the nature of these positions, the cash flow and earnings recognized on a GAAP basis will differ from period to period depending on the current crude oil price and future estimated crude oil price which are valued utilizing third-party market quoted prices. We are recognizing in Adjusted EBITDA the gains and losses from the derivative instrument positions entered into in January 2021 to properly align with the physical margin we are hedging each month through the term of this transaction. This representation aligns with management’s evaluation of the transaction.

The following table reconciles net income (loss) to EBITDA and Adjusted EBITDA for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Net income (loss)	$	58,982	$	(18,982)	$	85,695	$	(154,691)
Less: Net (income) loss attributable to noncontrolling interests	(448)		63		(790)		(705)
Net income (loss) attributable to NGL Energy Partners LP	58,534		(18,919)		84,905		(155,396)
Interest expense	75,934		68,395		211,573		204,037
Income tax (benefit) expense	(252)		(135)		113		(820)
Depreciation and amortization	69,308		68,452		204,025		221,352
EBITDA	203,524		117,793		500,616		269,173
Net unrealized losses (gains) on derivatives	4,800		(13,500)		(56,930)		(48,254)
CMA Differential Roll net losses (gains) (1)	(8,678)		23,872		19,424		60,987
Inventory valuation adjustment (2)	(2,650)		1,145		(6,765)		1,912
Lower of cost or net realizable value adjustments	(12,568)		2,921		(11,711)		2,636
Loss on disposal or impairment of assets, net	8,290		12,035		15,775		93,268
Gain on early extinguishment of liabilities, net	(2,667)		(9)		(6,808)		(1,168)
Equity-based compensation expense	890		749		1,866		(1,044)
Acquisition expense (3)	—		(36)		—		67
Other (4)	2,315		2,770		3,907		7,525
Adjusted EBITDA	$	193,256	$	147,740	$	459,374	$	385,102

(1)    Adjustment to align, within Adjusted EBITDA, the net gains and losses of the Partnership’s CMA Differential Roll derivative instruments positions with the physical margin being hedged. See “Non-GAAP Financial Measures” section above for a further discussion.

(2)    Amount reflects the difference between the market value of the inventory at the balance sheet date and its cost. See “Non-GAAP Financial Measures” section above for a further discussion.

(3)    Amounts represent expenses we incurred related to legal and advisory costs associated with acquisitions.

(4)    Amounts represent non-cash operating expenses related to our Grand Mesa Pipeline, unrealized gains/losses on marketable securities, accretion expense for asset retirement obligations and the write off of an asset acquired in a prior period acquisition.

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The following tables reconcile depreciation and amortization amounts per the EBITDA table above to depreciation and amortization amounts reported in our unaudited condensed consolidated statements of operations and unaudited condensed consolidated statements of cash flows for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Depreciation and amortization per EBITDA table	$	69,308	$	68,452	$	204,025	$	221,352
Intangible asset amortization recorded to cost of sales	(68)		(69)		(205)		(213)
Depreciation and amortization of unconsolidated entities	(193)		(187)		(557)		(545)
Depreciation and amortization attributable to noncontrolling interests	280		284		842		1,551
Depreciation and amortization per unaudited condensed consolidated statements of operations	$	69,327	$	68,480	$	204,105	$	222,145

	Nine Months Ended December 31,
	2022		2021
	(in thousands)
Depreciation and amortization per EBITDA table	$	204,025	$	221,352
Amortization of debt issuance costs recorded to interest expense	12,533		12,814
Amortization of royalty expense recorded to operating expense	185		185
Depreciation and amortization of unconsolidated entities	(557)		(545)
Depreciation and amortization attributable to noncontrolling interests	842		1,551
Depreciation and amortization per unaudited condensed consolidated statements of cash flows	$	217,028	$	235,357

The following table reconciles interest expense per the EBITDA table above to interest expense reported in our unaudited condensed consolidated statements of operations for the periods indicated:

	Three Months Ended December 31,				Nine Months Ended December 31,
	2022		2021		2022		2021
	(in thousands)
Interest expense per EBITDA table	$	75,934	$	68,395	$	211,573	$	204,037
Interest expense attributable to unconsolidated entities	(14)		(15)		(45)		(49)
Interest expense attributable to noncontrolling interests	—		(1)		—		16
Interest expense per unaudited condensed consolidated statements of operations	$	75,920	$	68,379	$	211,528	$	204,004

The following tables reconcile operating income (loss) to Adjusted EBITDA by segment for the periods indicated:

	Three Months Ended December 31, 2022
	Water Solutions		Crude Oil Logistics		Liquids Logistics		Corporate and Other		Consolidated
	(in thousands)
Operating income (loss)	$	59,721	$	35,096	$	20,513	$	(12,660)	$	102,670
Depreciation and amortization	52,591		11,664		3,417		1,655		69,327
Amortization recorded to cost of sales	—		—		68		—		68
Net unrealized (gains) losses on derivatives	—		(1,810)		6,610		—		4,800
CMA Differential Roll net losses (gains)	—		(8,678)		—		—		(8,678)
Inventory valuation adjustment	—		—		(2,650)		—		(2,650)
Lower of cost or net realizable value adjustments	—		(3,321)		(9,247)		—		(12,568)
Loss (gain) on disposal or impairment of assets, net	7,959		277		(1)		71		8,306
Equity-based compensation expense	—		—		—		890		890
Other income (expense), net	2		59		(1,481)		29,520		28,100
Adjusted EBITDA attributable to unconsolidated entities	1,357		—		21		45		1,423
Adjusted EBITDA attributable to noncontrolling interest	(747)		—		—		—		(747)
Other	829		(27)		1,513		—		2,315
Adjusted EBITDA	$	121,712	$	33,260	$	18,763	$	19,521	$	193,256

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	Three Months Ended December 31, 2021
	Water Solutions		Crude Oil Logistics		Liquids Logistics		Corporate and Other		Consolidated
	(in thousands)
Operating income (loss)	$	19,851	$	21,291	$	23,158	$	(15,190)	$	49,110
Depreciation and amortization	50,815		12,166		3,756		1,743		68,480
Amortization recorded to cost of sales	—		—		69		—		69
Net unrealized losses (gains) on derivatives	1,758		(32,201)		16,943		—		(13,500)
CMA Differential Roll net losses (gains)	—		23,872		—		—		23,872
Inventory valuation adjustment	—		—		1,145		—		1,145
Lower of cost or net realizable value adjustments	—		—		2,921		—		2,921
Loss (gain) on disposal or impairment of assets, net	9,997		2,262		(26)		—		12,233
Equity-based compensation expense	—		—		—		749		749
Acquisition expense	4		—		—		(40)		(36)
Other (expense) income, net	(6)		—		(31)		61		24
Adjusted EBITDA attributable to unconsolidated entities	384		—		10		(70)		324
Adjusted EBITDA attributable to noncontrolling interest	(419)		—		(3)		—		(422)
Other	360		2,374		37		—		2,771
Adjusted EBITDA	$	82,744	$	29,764	$	47,979	$	(12,747)	$	147,740

	Nine Months Ended December 31, 2022
	Water Solutions		Crude Oil Logistics		Liquids Logistics		Corporate and Other		Consolidated
	(in thousands)
Operating income (loss)	$	160,454	$	87,012	$	48,806	$	(37,569)	$	258,703
Depreciation and amortization	153,766		35,193		10,194		4,952		204,105
Amortization recorded to cost of sales	—		—		205		—		205
Net unrealized (gains) losses on derivatives	(4,464)		(57,390)		4,924		—		(56,930)
CMA Differential Roll net losses (gains)	—		19,424		—		—		19,424
Inventory valuation adjustment	—		—		(6,765)		—		(6,765)
Lower of cost or net realizable value adjustments	—		(2,247)		(9,464)		—		(11,711)
Loss (gain) on disposal or impairment of assets, net	17,935		(1,279)		51		(916)		15,791
Equity-based compensation expense	—		—		—		1,866		1,866
Other income (expense), net	10		390		(1,665)		29,996		28,731
Adjusted EBITDA attributable to unconsolidated entities	3,569		—		(3)		134		3,700
Adjusted EBITDA attributable to noncontrolling interest	(1,652)		—		—		—		(1,652)
Other	1,915		98		1,894		—		3,907
Adjusted EBITDA	$	331,533	$	81,201	$	48,177	$	(1,537)	$	459,374

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	Nine Months Ended December 31, 2021
	Water Solutions		Crude Oil Logistics		Liquids Logistics		Corporate and Other		Consolidated
	(in thousands)
Operating income (loss)	$	60,206	$	37,941	$	(18,790)	$	(34,763)	$	44,594
Depreciation and amortization	164,466		37,029		15,409		5,241		222,145
Amortization recorded to cost of sales	—		—		213		—		213
Net unrealized losses (gains) on derivatives	6,845		(53,808)		(1,291)		—		(48,254)
CMA Differential Roll net losses (gains)	—		60,987		—		—		60,987
Inventory valuation adjustment	—		—		1,912		—		1,912
Lower of cost or net realizable value adjustments	—		(11)		2,647		—		2,636
Loss on disposal or impairment of assets, net	19,450		2,206		71,807		—		93,463
Equity-based compensation expense	—		—		—		(1,044)		(1,044)
Acquisition expense	4		—		—		63		67
Other income, net	616		350		627		410		2,003
Adjusted EBITDA attributable to unconsolidated entities	1,559		—		(9)		(190)		1,360
Adjusted EBITDA attributable to noncontrolling interest	(1,987)		—		(529)		—		(2,516)
Other	520		6,994		22		—		7,536
Adjusted EBITDA	$	251,679	$	91,688	$	72,018	$	(30,283)	$	385,102

Liquidity, Sources of Capital and Capital Resource Activities

General

Our principal sources of liquidity and capital resource requirements are cash flows from our operations, borrowings under our asset-based revolving credit facility (“ABL Facility”), debt issuances and the issuance of common and preferred units. We expect our primary cash outflows to be related to capital expenditures, interest and repayment of debt maturities.

We believe that our anticipated cash flows from operations and the borrowing capacity under our ABL Facility will be sufficient to meet our liquidity needs, including the repayment of the 2023 Notes. Our borrowing needs vary during the year due in part to the seasonal nature of certain businesses within our Liquids Logistics segment. Our greatest working capital borrowing needs generally occur during the period of June through December, when we are building our natural gas liquids inventories in anticipation of the butane blending and heating seasons. Our working capital borrowing needs generally decline during the period of January through March, when the cash inflows from our Liquids Logistics segment are the greatest. In addition, our working capital borrowing needs vary with changes in commodity prices.

Cash Management

We manage cash by utilizing a centralized cash management program that concentrates the cash assets of our operating subsidiaries in joint accounts for the purposes of providing financial flexibility and lowering the cost of borrowing, transaction costs and bank fees. Our centralized cash management program provides that funds in excess of the daily needs of our operating subsidiaries are concentrated, consolidated or otherwise made available for use by other entities within our consolidated group. All of our wholly-owned operating subsidiaries participate in this program. Under the cash management program, depending on whether a participating subsidiary has short-term cash surpluses or cash requirements, we provide cash to the subsidiary or the subsidiary provides cash to us.

Short-Term Liquidity

Our principal sources of short-term liquidity consist of cash generated from operating activities and borrowings under our ABL Facility, which we believe will provide liquidity to operate our business, manage our working capital requirements and repay current maturities. Current commitments under the ABL Facility are $600.0 million, but as part of amending the ABL Facility on April 13, 2022, we agreed to reduce the commitments back to $500.0 million on or before March 31, 2023. We currently anticipate having minimal needs for acquisitions or expansion projects and expect to fund these items through cash flows from operations or borrowings under the ABL Facility. At December 31, 2022, $156.0 million had been borrowed under the ABL Facility and we had letters of credit outstanding of approximately $168.4 million. The ABL Facility is scheduled to mature at the earliest of (a) February 4, 2026 or (b) 91 days prior to the earliest maturity date in respect to any of our

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indebtedness in an aggregate principal amount of $50.0 million or greater, if such indebtedness is outstanding at such time, subject to certain exceptions. See below for further discussion on the timing of paying down the 2023 Notes.

We are currently working with the banking group under our ABL Facility to extend the additional $100 million of commitments currently available under the ABL Facility, which is set to expire on or before March 31, 2023.

As of December 31, 2022, our current assets exceeded our current liabilities by approximately $33.5 million.

For additional information related to our ABL Facility, see Note 6 to our unaudited condensed consolidated financial statements included in this Quarterly Report.

Long-Term Financing

In addition to our principal sources of short-term liquidity discussed above, we expect to fund our longer-term financing requirements by issuing long-term notes, common units and/or preferred units, loans from financial institutions, asset securitizations or the sale of assets.

Senior Secured Notes

On February 4, 2021, we issued $2.05 billion of 7.5% 2026 Senior Secured Notes (“2026 Senior Secured Notes”) in a private placement. The 2026 Senior Secured Notes bear interest, which is payable on February 1 and August 1 of each year, beginning on August 1, 2021. The 2026 Senior Secured Notes mature on February 1, 2026.

Senior Unsecured Notes

The senior unsecured notes include the 2023 Notes, which mature on November 1, 2023, the 6.125% senior unsecured notes due 2025 (“2025 Notes”), which mature on March 1, 2025 and the 7.5% senior unsecured notes due 2026 (“2026 Notes”), which mature on April 15, 2026 (collectively, the “Senior Unsecured Notes”).

Repurchases

During the three months ended December 31, 2022, we repurchased $97.5 million of the 2023 Notes at a total cash cost of $94.6 million (excluding payments of accrued interest). Subsequent to December 31, 2022, we have repurchased $98.5 million of the 2023 Notes and as of February 8, 2023, the outstanding balance of the 2023 Notes is $203.4 million.

We expect to pay off the remaining outstanding 2023 Notes no later than June 30, 2023, using cash flows from operations, and if needed, borrowings under our ABL Facility. Proceeds generated from other cash flow positive initiatives currently being pursued, such as sales of non-core assets, may also be used for additional debt reductions.

Redemption

We currently have the right to redeem all of the outstanding 2023 Notes at 100% of the principal amount plus accrued and unpaid interest. As of March 1, 2023, we will have the right to redeem all or a portion of the outstanding 2025 Notes at 100% of the principal amount plus accrued and unpaid interest. As of April 15, 2024, we will have the right to redeem all or a portion of the outstanding 2026 Notes at 100% of the principal amount plus accrued and unpaid interest.

Other Long-Term Debt

On October 29, 2020, we entered into an equipment loan for $45.0 million which bears interest at a rate of 8.6% and is secured by certain of our barges and towboats. Under this agreement, we are required to make monthly payments of $0.5 million (principal and interest) and a balloon payment of $23.9 million when this loan matures on November 1, 2027.

For additional information related to our long-term debt, see Note 6 to our unaudited condensed consolidated financial statements included in this Quarterly Report.

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Capital Expenditures, Acquisitions and Other Investments

The following table summarizes expansion and maintenance capital expenditures (which excludes additions for tank bottoms and linefill and has been prepared on the accrual basis), acquisitions and other investments for the periods indicated.

	Capital Expenditures						Other
	Expansion		Maintenance		Acquisitions (1)		Investments (2)
	(in thousands)
Three Months Ended December 31,
2022	$	11,208	$	11,464	$	—	$	—
2021	$	13,029	$	13,329	$	—	$	115
Nine Months Ended December 31,
2022	$	74,151	$	41,050	$	—	$	346
2021	$	57,552	$	38,053	$	—	$	350

(1)    There were no acquisitions during the three months or nine months ended December 31, 2022 or 2021.

(2)    Amounts for the three months ended December 31, 2021 and nine months ended December 31, 2022 and 2021 relate to contributions made to unconsolidated entities. There were no other investments during the three months ended December 31, 2022.

Capital expenditures for the fiscal year ending March 31, 2023 are expected to be approximately $115 - $125 million.

Distributions Declared

The board of directors of our GP decided to temporarily suspend all distributions in order to deleverage our balance sheet until we meet the 4.75 to 1.00 total leverage ratio set forth within the indenture of the 2026 Senior Secured Notes. This resulted in the suspension of the quarterly common unit distributions, which began with the quarter ended December 31, 2020, and all preferred unit distributions, which began with the quarter ended March 31, 2021. The board of directors of our GP expects to evaluate the reinstatement of the common unit and all preferred unit distributions in due course, taking into account a number of important factors, including our leverage, liquidity, the sustainability of cash flows, upcoming debt maturities, capital expenditures and the overall performance of our businesses.

Contractual Obligations

Our contractual obligations primarily consist of purchase commitments, outstanding debt principal and interest obligations, lease obligations, pipeline commitments, asset retirement obligations and other commitments.

For a discussion of contractual obligations, see Note 6, Note 7 and Note 13 to our unaudited condensed consolidated financial statements included in this Quarterly Report.

Cash Flows

The following table summarizes the sources (uses) of our cash flows for the periods indicated:

	Nine Months Ended December 31,
Cash Flows Provided by (Used in):	2022		2021
	(in thousands)
Operating activities, before changes in operating assets and liabilities	$	330,191	$	224,457
Changes in operating assets and liabilities	(123,326)		(197,546)
Operating activities	$	206,865	$	26,911
Investing activities	$	(72,067)	$	(96,501)
Financing activities	$	(134,086)	$	70,217

Operating Activities. The seasonality of our Liquids Logistics segment has a significant effect on our cash flows from operating activities. Increases in natural gas liquids prices typically reduce our operating cash flows due to higher cash requirements to fund increases in inventories and decreases in natural gas liquids prices typically increase our operating cash flows due to lower cash requirements to fund increases in inventories. In our Liquids Logistics segment, we typically experience operating losses or lower operating income during our first and second quarters, or the six months ending September

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30, as a result of lower volumes of natural gas liquids sales and when we are building our inventory levels for the upcoming butane blending and heating seasons, which generally begin in late fall, under normal demand conditions, and run through February or March. We borrow under the revolving credit facility to supplement our operating cash flows during the periods in which we are building inventory. Our operations, and as a result our cash flows, are also impacted by positive and negative movements in commodity prices, which cause fluctuations in the value of inventory, accounts receivable and payables, due to increases and decreases in revenues and cost of sales. The increase in net cash provided by operating activities during the nine months ended December 31, 2022 was due primarily to fluctuations in working capital, particularly accounts receivable, inventory and accounts payable, during the nine months ended December 31, 2022, and increased earnings from operations.

Investing Activities. Net cash used in investing activities was $72.1 million during the nine months ended December 31, 2022, compared to net cash used in investing activities of $96.5 million during the nine months ended December 31, 2021. The decrease in net cash used in investing activities was due primarily to:

•an $89.5 million decrease in payments to settle derivatives; and

•a $13.7 million increase in proceeds received from certain asset sales during the nine months ended December 31, 2022.

These decreases in net cash used in investing activities were partially offset by:

•lower proceeds from the divestitures of business and investments as we received net proceeds (gross cash proceeds less the amount of cash sold, excluding accrued expenses) of $63.5 million from the sale of our interest in Sawtooth in June 2021; and

•an increase in capital expenditures from $107.5 million (includes payment of amounts accrued as of March 31, 2021) during the nine months ended December 31, 2021 to $122.4 million (includes payment of amounts accrued as of March 31, 2022) during the nine months ended December 31, 2022 due primarily to the timing of the expenditures in our Water Solutions segment.

Financing Activities. Net cash used in financing activities was $134.1 million during the nine months ended December 31, 2022, compared to net cash provided by financing activities of $70.2 million during the nine months ended December 31, 2021. The increase in net cash used in financing activities was due primarily to:

•a decrease of $112.0 million in borrowings on the revolving credit facility (net of repayments) during the nine months ended December 31, 2022; and

•an increase of $107.9 million paid in cash to repurchase a portion of our Senior Unsecured Notes during the nine months ended December 31, 2022.

These increases in net cash used in financing activities were partially offset by:

•a decrease of $11.2 million in debt issuance costs for the revolving credit facility during the nine months ended December 31, 2022; and

•a decrease of $5.0 million in payments on other long-term debt as the Sawtooth credit agreement was paid off and terminated prior to us selling our ownership interest in Sawtooth in June 2021.

Supplemental Guarantor Information

NGL Energy Partners LP (parent) and NGL Energy Finance Corp. are co-issuers of the Senior Unsecured Notes (see Note 6 to our unaudited condensed consolidated financial statements included in this Quarterly Report). Certain of our wholly owned subsidiaries (“Guarantor Subsidiaries”) have, jointly and severally, fully and unconditionally guaranteed the Senior Unsecured Notes.

The guarantees are senior unsecured obligations of each Guarantor Subsidiary and rank equally in right of payment with other existing and future senior indebtedness of such Guarantor Subsidiary, and senior in right of payment to all existing and future subordinated indebtedness of such Guarantor Subsidiary. The guarantee of our Senior Unsecured Notes by each Guarantor Subsidiary is subject to certain automatic customary releases, including in connection with the sale, disposition or transfer of all of the capital stock, or of all or substantially all of the assets, of such Guarantor Subsidiary to one or more persons that are not us or a restricted subsidiary, the exercise of legal defeasance or covenant defeasance options, the satisfaction and discharge of the indentures governing our Senior Unsecured Notes, the designation of such Guarantor Subsidiary as a non-

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guarantor restricted subsidiary or as an unrestricted subsidiary in accordance with the indentures governing our Senior Unsecured Notes, the release of such Guarantor Subsidiary from its guarantee under our revolving credit facility, the liquidation or dissolution of such Guarantor Subsidiary or upon the consolidation, merger or transfer of all assets of the Guarantor Subsidiary to us or another Guarantor Subsidiary in which the Guarantor Subsidiary dissolves or ceases to exist (collectively, the “Releases”). The obligations of each Guarantor Subsidiary under its note guarantee are limited as necessary to prevent such note guarantee from constituting a fraudulent conveyance under applicable law. We are not restricted from making investments in the Guarantor Subsidiaries and there are no significant restrictions on the ability of the Guarantor Subsidiaries to make distributions to NGL Energy Partners LP (parent). None of the assets of the Guarantor Subsidiaries (other than the investments in non-guarantor subsidiaries) are restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X under the Securities Act of 1933, as amended.

The rights of holders of our Senior Unsecured Notes against the Guarantor Subsidiaries may be limited under the U.S. Bankruptcy Law, the Uniform Fraudulent Conveyance Act, the Uniform Fraudulent Transfer Act or any similar federal or state law.

In March 2020, the SEC adopted amendments to Rule 3-10 of Regulation S-X and created Rule 13-01 of Regulation S-X to simplify disclosure requirements related to certain registered securities. The amendments became effective on January 4, 2021. As a result of these amendments, parent company and co-issuer subsidiary obligations guaranteed by one or more consolidated subsidiaries are not required to provide separate financial statements, provided that each subsidiary issuer/guarantor is consolidated into the parent company’s consolidated financial statements, the parent company issues the obligations and the alternative disclosure required by Rule 13-01 is provided, which includes narrative disclosure and, subject to certain exceptions, summarized financial information. Accordingly, as permitted under Rule 13-01(a)(4)(vi), we have excluded summarized financial information for the Partnership because the assets, liabilities, and results of operations of NGL Energy Partners LP (parent), NGL Energy Finance Corp. and the Guarantor Subsidiaries are not materially different than the corresponding amounts in our consolidated financial statements, and we believe that such summarized financial information would be repetitive and would not provide incremental value to investors.

Environmental Legislation

See our Annual Report for a discussion of proposed environmental legislation and regulations that, if enacted, could result in increased compliance and operating costs. However, at this time we cannot predict the structure or outcome of any future legislation or regulations or the eventual cost we could incur in compliance.

Recent Accounting Pronouncements

For a discussion of recent accounting pronouncements that are applicable to us, see Note 2 to our unaudited condensed consolidated financial statements included in this Quarterly Report.

Critical Accounting Estimates

The preparation of financial statements and related disclosures in conformity with GAAP requires the selection and application of appropriate accounting principles to the relevant facts and circumstances of our operations and the use of estimates made by management. We have identified certain more critical judgment areas in the application of our accounting policies that are most important to the portrayal of our consolidated financial position and results of operations. The application of these accounting policies, which requires subjective or complex judgments regarding estimates and projected outcomes of future events, and changes in these accounting policies, could have a material effect on our consolidated financial statements. There have been no material changes in the critical accounting estimates previously disclosed in our Annual Report.

Item 3.    Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

A portion of our long-term debt is variable-rate debt. Changes in interest rates impact the interest payments of our variable-rate debt but generally do not impact the fair value of the liability. Conversely, changes in interest rates impact the fair value of our fixed-rate debt but do not impact its cash flows.

The ABL Facility is variable-rate debt with interest rates that are generally indexed to the prime rate or SOFR, an adjusted forward-looking term rate based on the secured overnight financing rate. At December 31, 2022, we had $156.0 million of outstanding borrowings under the ABL Facility at a weighted average interest rate of 7.37%. A change in interest

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rates of 0.125% would result in an increase or decrease of our annual interest expense of $0.2 million, based on borrowings outstanding at December 31, 2022.

On July 1, 2022, the Class B Preferred Units distribution rate changed from a fixed rate of 9.00% to a floating rate of the three-month London Interbank Offered Rate (“LIBOR”) interest rate (3.75% for the quarter ended December 31, 2022) plus a spread of 7.21%. A change in interest rates of 0.125% would result in an increase or decrease of our Class B Preferred Unit distribution of $0.1 million, based on the Class B Preferred Units outstanding at December 31, 2022.

For our Class C Preferred Units, distributions on and after April 15, 2024 will accumulate at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR interest rate (or alternative rate as determined in the amended and restated limited partnership agreement (the “Partnership Agreement”)) plus a spread of 7.384%. On or after July 1, 2024, the holders of our Class D Preferred Units can elect, from time to time, for the distributions to be calculated based on a floating rate equal to the applicable three-month LIBOR interest rate (or alternative rate as determined in the Partnership Agreement) plus a spread of 7.00% (“Class D Variable Rate”, as defined in the Partnership Agreement). Each Class D Variable Rate election shall be effective for at least four quarters following such election.

Commodity Price Risk

Our operations are subject to certain business risks, including commodity price risk. Commodity price risk is the risk that the market value of crude oil, natural gas liquids, or refined and renewables products will change, either favorably or unfavorably, in response to changing market conditions. Procedures and limits for managing commodity price risks are specified in our market risk policy. Open commodity positions and market price changes are monitored daily and are reported to senior management and to marketing operations personnel.

The crude oil, natural gas liquids, and refined and renewables products industries are “margin-based” and “cost-plus” businesses in which gross profits depend on the differential of sales prices over supply costs. We have no control over market conditions. As a result, our profitability may be impacted by sudden and significant changes in the price of crude oil, natural gas liquids, and refined and renewables products.

We engage in various types of forward contracts and financial derivative transactions to reduce the effect of price volatility on our product costs, to protect the value of our inventory positions, and to help ensure the availability of product during periods of short supply. We attempt to balance our contractual portfolio by purchasing volumes when we have a matching purchase commitment from our wholesale and retail customers. We may experience net unbalanced positions from time to time. In addition to our ongoing policy to maintain a balanced position, for accounting purposes we are required, on an ongoing basis, to track and report the market value of our derivative portfolio.

Although we use financial derivative instruments to reduce the market price risk associated with forecasted transactions, we do not account for financial derivative transactions as hedges. All changes in the fair value of our physical contracts that do not qualify as normal purchases and normal sales and settlements (whether cash transactions or non-cash mark-to-market adjustments) are reported either within revenue (for sales contracts) or cost of sales (for purchase contracts) in our unaudited condensed consolidated statements of operations, regardless of whether the contract is physically or financially settled.

The following table summarizes the hypothetical impact on the December 31, 2022 fair value of our commodity derivatives of an increase of 10% in the value of the underlying commodity (in thousands):

	Increase (Decrease) To Fair Value
Crude oil (Crude Oil Logistics segment)	$	(3,811)
Propane (Liquids Logistics segment)	$	(605)
Butane (Liquids Logistics segment)	$	(1,270)
Refined Products (Liquids Logistics segment)	$	(5,126)
Other Products (Liquids Logistics segment)	$	10,101
Canadian dollars (Liquids Logistics segment)	$	124

Changes in commodity prices may also impact the volumes that we are able to transport, dispose, store and market, which also impact our cash flows.

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Credit Risk

Our operations are also subject to credit risk, which is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. Procedures and limits for managing credit risk are specified in our credit policy. Credit risk is monitored daily and we believe we minimize exposure through the following:

•requiring certain customers to prepay or place deposits for our products and services;

•requiring certain customers to post letters of credit or other forms of surety;

•monitoring individual customer receivables relative to previously-approved credit limits;

•requiring certain customers to take delivery of their contracted volume ratably rather than allow them to take delivery at their discretion;

•entering into master netting agreements that allow for offsetting counterparty receivable and payable balances for certain transactions;

•reviewing the receivable aging regularly to identify issues or trends that may develop; and

•requiring marketing personnel to manage their customers’ receivable position and suspend sales to customers that have not timely paid outstanding invoices.

At December 31, 2022, our primary counterparties were retailers, resellers, energy marketers, producers, refiners, and dealers.

Fair Value

We determine the fair value of our exchange traded derivative financial instruments utilizing publicly available prices, and for non-exchange traded derivative financial instruments, we utilize pricing models for similar instruments including publicly available prices and forward curves generated from a compilation of data gathered from third-parties.

Item 4.    Controls and Procedures

We maintain disclosure controls and procedures, as defined in Rule 13(a)-15(e) and 15(d)-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), that are designed to ensure the information required to be disclosed in our filings and submissions under the Exchange Act is recorded, processed, summarized and reported within the periods specified in the rules and forms of the Securities and Exchange Commission and that such information is accumulated and communicated to our management, including the principal executive officer and principal financial officer of our general partner, as appropriate, to allow timely decisions regarding required disclosure.

We completed an evaluation under the supervision and with participation of our management, including the principal executive officer and principal financial officer of our general partner, of the effectiveness of the design and operation of our disclosure controls and procedures at December 31, 2022. Based on this evaluation, the principal executive officer and principal financial officer of our general partner have concluded that as of December 31, 2022, such disclosure controls and procedures were effective.

There have been no changes in our internal controls over financial reporting (as defined in Rule 13(a)-15(f) of the Exchange Act) during the three months ended December 31, 2022 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

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PART II - OTHER INFORMATION

Item 1.    Legal Proceedings

We are involved from time to time in various legal proceedings and claims arising in the ordinary course of business. For information related to legal proceedings, see the discussion under the caption “Legal Contingencies” in Note 7 to our unaudited condensed consolidated financial statements included in this Quarterly Report, which is incorporated by reference into this Item 1.

Item 1A.    Risk Factors

There have been no material changes in the risk factors previously disclosed in Part I, Item 1A–“Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended March 31, 2022.

Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds

During November 2022, 31,828 common units were surrendered by employees to pay tax withholding in connection with the vesting of restricted common units. As a result, we are deeming the surrenders to be “repurchases.” The average price paid per common unit was $1.31. These repurchases were not part of a publicly announced program to repurchase our common units, nor do we have a publicly announced program to repurchase our common units.

Item 3.    Defaults Upon Senior Securities

Pursuant to certain covenants within the indenture of our 2026 Senior Secured Notes, the board of directors of our general partner temporarily suspended all common unit and preferred unit distributions. For additional information related to the suspension of distributions, see Note 8 to our unaudited condensed consolidated financial statements included in this Quarterly Report.

Item 4.    Mine Safety Disclosures

Not applicable.

Item 5.    Other Information

None.

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Item 6.    Exhibits

Exhibit Number	Exhibit
22.1	List of Issuers and Guarantor Subsidiaries of NGL Energy Partners LP (incorporated by reference to Exhibit 22.1 to the Annual Report on Form 10-K (File No. 001-35172) for the year ended March 31, 2022 filed with the SEC on June 6, 2022)
31.1*	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2*	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1*	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2*	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS**	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH**	Inline XBRL Schema Document
101.CAL**	Inline XBRL Calculation Linkbase Document
101.DEF**	Inline XBRL Definition Linkbase Document
101.LAB**	Inline XBRL Label Linkbase Document
101.PRE**	Inline XBRL Presentation Linkbase Document
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

*    Exhibits filed with this report.

**    The following documents are formatted in Inline XBRL (Extensible Business Reporting Language): (i) Unaudited Condensed Consolidated Balance Sheets at December 31, 2022 and March 31, 2022, (ii) Unaudited Condensed Consolidated Statements of Operations for the three months and nine months ended December 31, 2022 and 2021, (iii) Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) for the three months and nine months ended December 31, 2022 and 2021, (iv) Unaudited Condensed Consolidated Statements of Changes in Equity for the three months and nine months ended December 31, 2022 and 2021, (v) Unaudited Condensed Consolidated Statements of Cash Flows for the nine months ended December 31, 2022 and 2021, and (vi) Notes to Unaudited Condensed Consolidated Financial Statements.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	NGL ENERGY PARTNERS LP
	By:	NGL Energy Holdings LLC, its general partner
Date: February 9, 2023		By:	/s/ H. Michael Krimbill
			H. Michael Krimbill
			Chief Executive Officer
Date: February 9, 2023		By:	/s/ Brad Cooper
			Brad Cooper
			Chief Financial Officer

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