10-Q

Table of Contents

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 June 30, 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 August 4, 2022, there were 130,695,970 common units issued and outstanding.

Table of Contents

TABLE OF CONTENTS

PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Unaudited Condensed Consolidated Balance Sheets at June 30, 2022 and March 31, 2022	3
	Unaudited Condensed Consolidated Statements of Operations for the three months ended June 30, 2022 and 2021	4
	Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) for the three months ended June 30, 2022 and 2021	5
	Unaudited Condensed Consolidated Statements of Changes in Equity for the three months ended June 30, 2022 and 2021	6
	Unaudited Condensed Consolidated Statements of Cash Flows for the three months ended June 30, 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	30
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	47
Item 4.	Controls and Procedures	48
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	50
Item 1A.	Risk Factors	50
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	50
Item 3.	Defaults Upon Senior Securities	50
Item 4.	Mine Safety Disclosures	50
Item 5.	Other Information	50
Item 6.	Exhibits	51
SIGNATURES		52

i

Table of Contents

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;

•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;

•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;

Table of Contents

•changes in general economic conditions, including market and macroeconomic disruptions resulting from pandemics, including the current COVID-19 pandemic, 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.

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1.    Financial Statements

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Balance Sheets

(in Thousands, except unit amounts)

	June 30, 2022		March 31, 2022
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	816	$	3,822
Accounts receivable-trade, net of allowance for expected credit losses of $2,625 and $2,626, respectively	1,304,831		1,123,163
Accounts receivable-affiliates	9,238		8,591
Inventories	301,298		251,277
Prepaid expenses and other current assets	133,135		159,486
Total current assets	1,749,318		1,546,339
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation of $918,150 and $887,006, respectively	2,455,580		2,462,390
GOODWILL	744,439		744,439
INTANGIBLE ASSETS, net of accumulated amortization of $527,994 and $507,285, respectively	1,116,122		1,135,354
INVESTMENTS IN UNCONSOLIDATED ENTITIES	22,571		21,897
OPERATING LEASE RIGHT-OF-USE ASSETS	107,176		114,124
OTHER NONCURRENT ASSETS	42,352		45,802
Total assets	$	6,237,558	$	6,070,345
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Accounts payable-trade	$	1,150,270	$	1,084,837
Accounts payable-affiliates	91		73
Accrued expenses and other payables	179,101		140,719
Advance payments received from customers	21,819		7,934
Current maturities of long-term debt	2,430		2,378
Operating lease obligations	38,667		41,261
Total current liabilities	1,392,378		1,277,202
LONG-TERM DEBT, net of debt issuance costs of $39,938 and $42,988, respectively, and current maturities	3,384,571		3,350,463
OPERATING LEASE OBLIGATIONS	68,963		72,784
OTHER NONCURRENT LIABILITIES	103,518		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, 130,827 and 130,827 notional units, respectively	(52,483)		(52,478)
Limited partners, representing a 99.9% interest, 130,695,970 and 130,695,970 common units issued and outstanding, respectively	424,849		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	(358)		(308)
Noncontrolling interests	16,664		17,394
Total equity	737,031		714,453
Total liabilities and equity	$	6,237,558	$	6,070,345

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

Table of Contents

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Operations

(in Thousands, except unit and per unit amounts)

	Three Months Ended June 30,
	2022		2021
REVENUES:
Water Solutions	$	166,079	$	130,226
Crude Oil Logistics	865,371		553,624
Liquids Logistics	1,465,933		804,805
Total Revenues	2,497,383		1,488,655
COST OF SALES:
Water Solutions	10,225		10,338
Crude Oil Logistics	822,370		537,257
Liquids Logistics	1,422,416		777,198
Total Cost of Sales	2,255,011		1,324,793
OPERATING COSTS AND EXPENSES:
Operating	71,860		65,784
General and administrative	16,757		15,774
Depreciation and amortization	66,660		84,102
(Gain) loss on disposal or impairment of assets, net	(168)		67,536
Operating Income (Loss)	87,263		(69,334)
OTHER INCOME (EXPENSE):
Equity in earnings of unconsolidated entities	674		212
Interest expense	(67,311)		(67,130)
Gain on early extinguishment of liabilities, net	1,662		51
Other income, net	646		1,249
Income (Loss) Before Income Taxes	22,934		(134,952)
INCOME TAX BENEFIT	172		450
Net Income (Loss)	23,106		(134,502)
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	(245)		(438)
NET INCOME (LOSS) ATTRIBUTABLE TO NGL ENERGY PARTNERS LP	$	22,861	$	(134,940)
NET LOSS ALLOCATED TO COMMON UNITHOLDERS (NOTE 3)	$	(4,679)	$	(159,332)
BASIC LOSS PER COMMON UNIT	$	(0.04)	$	(1.23)
DILUTED LOSS PER COMMON UNIT	$	(0.04)	$	(1.23)
BASIC WEIGHTED AVERAGE COMMON UNITS OUTSTANDING	130,695,970		129,593,939
DILUTED WEIGHTED AVERAGE COMMON UNITS OUTSTANDING	130,695,970		129,593,939

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

Table of Contents

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)

(in Thousands)

	Three Months Ended June 30,
	2022		2021
Net income (loss)	$	23,106	$	(134,502)
Other comprehensive (loss) income	(50)		8
Comprehensive income (loss)	$	23,056	$	(134,494)

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

Table of Contents

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Equity

Three Months Ended June 30, 2022

(in Thousands, except unit amounts)

			Limited Partners
			Preferred			Common			Accumulated<br>Other
	General<br>Partner		Units	Amount		Units	Amount		Comprehensive<br>Income (Loss)		Noncontrolling<br>Interests		Total<br>Equity
BALANCES 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)
BALANCES AT JUNE 30, 2022	$	(52,483)	14,385,642	$	348,359	130,695,970	$	424,849	$	(358)	$	16,664	$	737,031

Table of Contents

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Equity

Three Months Ended June 30, 2021

(in Thousands, except unit amounts)

			Limited Partners
			Preferred			Common			Accumulated<br>Other
	General<br>Partner		Units	Amount		Units	Amount		Comprehensive<br>Income (Loss)		Noncontrolling<br>Interests		Total<br>Equity
BALANCES AT MARCH 31, 2021	$	(52,189)	14,385,642	$	348,359	129,593,999	$	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
BALANCES AT JUNE 30, 2021	$	(52,348)	14,385,642	$	348,359	129,593,999	$	448,963	$	(258)	$	18,368	$	763,084

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

Table of Contents

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Cash Flows

(in Thousands)

	Three Months Ended June 30,
	2022		2021
OPERATING ACTIVITIES:
Net income (loss)	$	23,106	$	(134,502)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization, including amortization of debt issuance costs	70,968		87,981
Gain on early extinguishment of liabilities, net	(1,662)		(51)
Non-cash equity-based compensation expense	497		960
(Gain) loss on disposal or impairment of assets, net	(168)		67,536
Change in provision for expected credit losses	(419)		(21)
Net adjustments to fair value of commodity derivatives	41,068		56,657
Equity in earnings of unconsolidated entities	(674)		(212)
Distributions of earnings from unconsolidated entities	—		1,379
Lower of cost or net realizable value adjustments	5,475		92
Other	1,395		469
Changes in operating assets and liabilities, exclusive of acquisitions:
Accounts receivable-trade and affiliates	(181,341)		(117,733)
Inventories	(55,507)		(96,816)
Other current and noncurrent assets	(4,613)		31,687
Accounts payable-trade and affiliates	66,927		83,753
Other current and noncurrent liabilities	37,434		13,658
Net cash provided by (used in) operating activities	2,486		(5,163)
INVESTING ACTIVITIES:
Capital expenditures	(41,006)		(46,760)
Net settlements of commodity derivatives	(2,267)		(59,857)
Proceeds from sales of assets	6,851		126
Proceeds from divestitures of businesses and investments, net	—		63,489
Investments in unconsolidated entities	—		(116)
Distributions of capital from unconsolidated entities	—		243
Net cash used in investing activities	(36,422)		(42,875)
FINANCING ACTIVITIES:
Proceeds from borrowings under revolving credit facility	552,000		304,000
Payments on revolving credit facility	(497,000)		(231,000)
Repayment and repurchase of senior unsecured notes	(21,517)		(18,393)
Payments on other long-term debt	(630)		(5,578)
Debt issuance costs	(592)		(2,416)
Distributions to noncontrolling interest owners	(975)		(444)
Payments to settle contingent consideration liabilities	(356)		(489)
Net cash provided by financing activities	30,930		45,680
Net decrease in cash and cash equivalents	(3,006)		(2,358)
Cash and cash equivalents, beginning of period	3,822		4,829
Cash and cash equivalents, end of period	$	816	$	2,471
Supplemental cash flow information:
Cash interest paid	$	34,166	$	35,522
Income taxes paid (net of income tax refunds)	$	1,748	$	1,299
Supplemental non-cash investing and financing activities:
Accrued capital expenditures	$	20,273	$	6,944

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

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 June 30, 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.

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 $42.9 million and $43.5 million at June 30, 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 three months ended June 30, 2022 was $0.7 million with an effective tax rate of 24.1%. The deferred tax benefit recorded during the three months ended June 30, 2021 was $1.1 million with an effective tax rate of 23.1%.

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 June 30, 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:

	June 30, 2022		March 31, 2022
	(in thousands)
Crude oil	$	91,345	$	135,485
Propane	81,101		43,971
Butane	71,929		33,144
Biodiesel	37,550		20,474
Diesel	3,801		3,504
Ethanol	3,698		3,503
Other	11,874		11,196
Total	$	301,298	$	251,277

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	June 30, 2022		March 31, 2022
			(in thousands)
Water services and land company	Water Solutions	50%	$	16,264	$	15,714
Water services and land company	Water Solutions	10%	2,898		2,863
Water services and land company	Water Solutions	50%	2,381		2,210
Aircraft company (1)	Corporate and Other	50%	473		538
Water services company	Water Solutions	50%	409		409
Natural gas liquids terminal company	Liquids Logistics	50%	146		163
Total			$	22,571	$	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:

	June 30, 2022		March 31, 2022
	(in thousands)
Linefill (1)	$	28,065	$	28,065
Minimum shipping fees - pipeline commitments (2)	7,831		8,899
Loan receivable (3)	1,039		3,147
Other	5,417		5,691
Total	$	42,352	$	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 June 30, 2022 and March 31, 2022, linefill consisted of 423,978 barrels of crude oil. 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). As of June 30, 2022, the deficiency credit was $12.1 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 three months ended June 30, 2022, we received a $2.0 million prepayment for this loan receivable and also reduced the final payment due July 31, 2023 to $1.1 million. We discounted the final payment to its net present value with the amount of the reduction in the value of the final payment recorded as a loss within (gain) loss on disposal or impairment of assets, net in our unaudited condensed consolidated statement of operations.

Accrued Expenses and Other Payables

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

	June 30, 2022		March 31, 2022
	(in thousands)
Accrued interest	$	85,063	$	56,104
Derivative liabilities	23,013		27,108
Accrued compensation and benefits	16,622		18,417
Excise and other tax liabilities	10,301		10,451
Product exchange liabilities	8,211		853
Other	35,891		27,786
Total	$	179,101	$	140,719

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 LIBOR or another reference rate expected to be discontinued because of reference rate reform. This guidance is effective prospectively upon issuance through December 31, 2022 and may be applied from the beginning of an interim period that includes the issuance date of this ASU. 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—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 June 30,
	2022	2021
Weighted average common units outstanding during the period:
Common units - Basic	130,695,970	129,593,939
Common units - Diluted	130,695,970	129,593,939

For the three months ended June 30, 2022 and 2021, all potential common units or convertible securities were considered antidilutive.

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

	Three Months Ended June 30,
	2022		2021
	(in thousands, except unit and per unit amounts)
Net income (loss)	$	23,106	$	(134,502)
Less: Net income attributable to noncontrolling interests	(245)		(438)
Net income (loss) attributable to NGL Energy Partners LP	22,861		(134,940)
Less: Distributions to preferred unitholders (1)	(27,545)		(24,551)
Less: Net loss allocated to GP (2)	5		159
Net loss allocated to common unitholders	$	(4,679)	$	(159,332)
Basic loss per common unit	$	(0.04)	$	(1.23)
Diluted loss per common unit	$	(0.04)	$	(1.23)
Basic weighted average common units outstanding	130,695,970		129,593,939
Diluted weighted average common units outstanding	130,695,970		129,593,939

(1)    Includes cumulative distributions for the three months ended June 30, 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 loss allocated to the GP includes distributions to which it is entitled as the holder of incentive distribution rights.

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Note 4—Property, Plant and Equipment

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

Description	Estimated<br>Useful Lives			June 30, 2022		March 31, 2022
	(in years)			(in thousands)
Natural gas liquids terminal and storage assets	2	-	30	$	173,815	$	173,199
Pipeline and related facilities	30	-	40	265,643		265,643
Vehicles and railcars	3	-	25	92,819		93,126
Water treatment facilities and equipment	3	-	30	2,048,478		2,040,687
Crude oil tanks and related equipment	2	-	30	236,845		236,805
Barges and towboats	5	-	30	145,123		138,778
Information technology equipment	3	-	7	48,309		48,664
Buildings and leasehold improvements	3	-	40	148,366		151,071
Land				99,567		100,038
Tank bottoms and linefill (1)				30,454		30,443
Other	3	-	20	15,225		15,252
Construction in progress				69,086		55,690
				3,373,730		3,349,396
Accumulated depreciation				(918,150)		(887,006)
Net property, plant and equipment				$	2,455,580	$	2,462,390

(1)    Tank bottoms, which are product volumes required for the operation of storage tanks, are recorded at historical cost. We recover tank bottoms when the storage tanks are removed from service. 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.

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

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Depreciation expense	$	47,051	$	60,606
Capitalized interest expense	$	249	$	332

We record (gains) losses from the sales of property, plant and equipment and any write-downs in value due to impairment within (gain) 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 period indicated:

	Three Months Ended June 30,
	2022
	(in thousands)
Water Solutions	$	1,412
Crude Oil Logistics	(1,370)
Total	$	42

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Note 5—Intangible Assets

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

		June 30, 2022						March 31, 2022
Description	Weighted-Average Remaining Useful Life	Gross Carrying<br>Amount		Accumulated<br>Amortization		Net		Gross Carrying<br>Amount		Accumulated<br>Amortization		Net
	(in years)	(in thousands)
Amortizable:
Customer relationships	19.3	$	1,200,919	$	(451,372)	$	749,547	$	1,200,919	$	(436,837)	$	764,082
Customer commitments	22.0	192,000		(23,040)		168,960		192,000		(21,120)		170,880
Pipeline capacity rights	21.4	7,799		(2,232)		5,567		7,799		(2,167)		5,632
Rights-of-way and easements	31.6	91,886		(12,908)		78,978		91,664		(12,201)		79,463
Water rights	16.9	99,869		(21,916)		77,953		99,869		(20,404)		79,465
Executory contracts and other agreements	22.9	21,346		(3,491)		17,855		20,931		(3,014)		17,917
Non-compete agreements	0.8	7,000		(6,817)		183		7,000		(6,487)		513
Debt issuance costs (1)	3.7	23,042		(6,218)		16,824		22,202		(5,055)		17,147
Total amortizable		1,643,861		(527,994)		1,115,867		1,642,384		(507,285)		1,135,099
Non-amortizable:
Trade names		255		—		255		255		—		255
Total		$	1,644,116	$	(527,994)	$	1,116,122	$	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.

Amortization expense is as follows for the periods indicated:

	Three Months Ended June 30,
Recorded In	2022		2021
	(in thousands)
Depreciation and amortization	$	19,609	$	23,496
Cost of sales	68		73
Interest expense	1,163		682
Operating expenses	62		62
Total	$	20,902	$	24,313

The following table summarizes expected amortization of our intangible assets at June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	61,751
2024	75,923
2025	67,706
2026	64,853
2027	60,259
2028	57,407
Thereafter	727,968
Total	$	1,115,867

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

Note 6—Long-Term Debt

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

	June 30, 2022						March 31, 2022
	Face<br>Amount		Unamortized<br>Debt Issuance<br>Costs (1)		Book<br>Value		Face<br>Amount		Unamortized<br>Debt Issuance<br>Costs (1)		Book<br>Value
	(in thousands)
Senior secured notes:
7.500% Notes due 2026 (“2026 Senior Secured Notes”)	$	2,050,000	$	(32,886)	$	2,017,114	$	2,050,000	$	(35,140)	$	2,014,860
Asset-based revolving credit facility (“ABL Facility”)	171,000		—		171,000		116,000		—		116,000
Senior unsecured notes:
7.500% Notes due 2023 (“2023 Notes”)	452,442		(1,516)		450,926		475,702		(1,873)		473,829
6.125% Notes due 2025 (“2025 Notes”)	380,020		(2,245)		377,775		380,020		(2,456)		377,564
7.500% Notes due 2026 (“2026 Notes”)	332,402		(3,235)		329,167		332,402		(3,460)		328,942
Other long-term debt	41,075		(56)		41,019		41,705		(59)		41,646
	3,426,939		(39,938)		3,387,001		3,395,829		(42,988)		3,352,841
Less: Current maturities	2,430		—		2,430		2,378		—		2,378
Long-term debt	$	3,424,509	$	(39,938)	$	3,384,571	$	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.

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 June 30, 2022, we were in compliance with the covenants under the 2026 Senior Secured Notes Indenture.

ABL Facility

The $500.0 million ABL Facility is subject to a borrowing base, which includes a sub-limit for letters of credit. The initial borrowing base was $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

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

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 June 30, 2022, $171.0 million had been borrowed under the ABL Facility and we had letters of credit outstanding of approximately $143.6 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 June 30, 2022, the borrowings under the ABL Facility had a weighted average interest rate of 4.84% calculated as the prime rate of 4.75% plus a margin of 1.75% on the alternate base borrowings and the weighted average SOFR of 1.28% plus a margin of 2.75% for the SOFR borrowings. On June 30, 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 June 30, 2022, no Cash Dominion Event had occurred.

Compliance

At June 30, 2022, we were in compliance with the covenants under the ABL Facility.

Senior Unsecured Notes

The senior unsecured notes include the 2023 Notes, 2025 Notes and 2026 Notes (collectively, the “Senior Unsecured Notes”).

Repurchases

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

	Three Months Ended June 30,
	2022
	(in thousands)
2023 Notes
Notes repurchased	$	23,260
Cash paid (excluding payments of accrued interest)	$	21,517
Gain on early extinguishment of debt (1)	$	1,662

(1)    Gain on early extinguishment of debt for the three months ended June 30, 2022 is inclusive of the write-off of debt issuance costs of $0.1 million. The gain is reported within gain on early extinguishment of liabilities, net within our unaudited condensed consolidated statement of operations.

Compliance

At June 30, 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 $41.1 million at June 30, 2022. The loan matures on November 1, 2027.

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 June 30, 2022:

Fiscal Year Ending March 31,	2026 Senior Secured Notes		ABL Facility		Senior Unsecured Notes		Other<br>Long-Term<br>Debt		Total
	(in thousands)
2023 (nine months)	$	—	$	—	$	—	$	1,748	$	1,748
2024	—		—		452,442		2,816		455,258
2025	—		—		380,020		3,068		383,088
2026	2,050,000		171,000		—		3,343		2,224,343
2027	—		—		332,402		3,642		336,044
2028	—		—		—		26,458		26,458
Total	$	2,050,000	$	171,000	$	1,164,864	$	41,075	$	3,426,939

Amortization of Debt Issuance Costs

Amortization expense for debt issuance costs related to long-term debt was $3.0 million and $3.1 million during the three months ended June 30, 2022 and 2021, respectively.

The following table summarizes expected amortization of debt issuance costs at June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	9,007
2024	11,540
2025	10,807
2026	8,532
2027	46
2028	6
Total	$	39,938

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 date for a new trial, to be limited to the quantum meruit claim, has been set by the trial court for November 7, 2022. 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 June 30, 2022, we have accrued $2.5 million related to this matter.

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

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 June 30, 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	146
Liabilities associated with disposed assets (1)	(85)
Liabilities settled	(93)
Accretion expense	441
Balance at June 30, 2022	$	30,350

(1)    Relates to the sale of two saltwater disposal wells.

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.

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).

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

The following table summarizes future minimum throughput payments under these agreements at June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	26,510
2024	35,410
2025	30,897
Total	$	92,817

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 June 30, 2022, we had the following commodity purchase commitments:

	Crude Oil (1)			Natural Gas Liquids
	Value		Volume<br>(in barrels)	Value		Volume<br>(in gallons)
	(in thousands)
Fixed-Price Commodity Purchase Commitments:
2023 (nine months)	$	163,726	1,486	$	9,884	10,501
2024	—		—	6,631		8,064
2025	—		—	1,096		1,260
Total	$	163,726	1,486	$	17,611	19,825
Index-Price Commodity Purchase Commitments:
2023 (nine months)	$	3,404,964	34,981	$	1,208,867	881,618
2024	2,429,375		29,877	55,243		51,533
2025	1,688,355		22,775	6,623		10,500
2026	690,326		10,409	—		—
Total	$	8,213,020	98,042	$	1,270,733	943,651

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

At June 30, 2022, we had the following commodity sale commitments:

	Crude Oil			Natural Gas Liquids
	Value		Volume<br>(in barrels)	Value		Volume<br>(in gallons)
	(in thousands)
Fixed-Price Commodity Sale Commitments:
2023 (nine months)	$	164,585	1,486	$	180,624	132,794
2024	—		—	13,418		14,078
2025	—		—	979		916
Total	$	164,585	1,486	$	195,021	147,788
Index-Price Commodity Sale Commitments:
2023 (nine months)	$	2,741,022	26,913	$	1,001,257	669,878
2024	924,914		10,858	23,565		19,138
2025	791,056		10,220	—		—
2026	28,963		390	—		—
Total	$	4,485,955	48,381	$	1,024,822	689,016

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

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 $37.9 million of our prepaid expenses and other current assets and $19.9 million of our accrued expenses and other payables at June 30, 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 June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	8,199
2024	8,468
2025	3,236
2026	1,203
2027	1,189
2028	1,189
Thereafter	4,140
Total	$	27,624

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. This agreement expires on December 31, 2022. For the three months ended June 30, 2022 and 2021, we recorded $0.4 million and $0.6 million, respectively, within operating expense in our unaudited condensed consolidated statements of operations. At June 30, 2022, the range of potential payments we could be obligated to make pursuant to the subsidy agreement could be from $0.0 million to $1.6 million.

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 us to maintain its 0.1% GP interest. Our GP is not required to guarantee or pay any of our debts and obligations. At June 30, 2022, we owned 8.69% of our GP.

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 June 30, 2022, there were 12,585,642 of our 9.00% Class B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (“Class B Preferred Units”) outstanding.

The current distribution rate for the Class B Preferred Units is 9.00% per year of the $25.00 liquidation preference per unit (equal to $2.25 per unit per year). For the quarter ended June 30, 2022, we did not declare or pay distributions to the holders of the Class B Preferred Units, thus the quarterly distribution for June 30, 2022 is $0.5625 and the cumulative distribution since suspension for each Class B Preferred Unit is $3.375. In addition, the amount of cumulative but unpaid

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 June 30, 2022 is $44.7 million.

On July 1, 2022, the Class B Preferred Units distributions on and after July 1, 2022 began accumulating at a percentage of the $25.00 liquidation preference equal to the applicable three-month LIBOR interest rate (or alternative rate as determined in accordance with the partnership agreement) plus a spread of 7.213%.

Class C Preferred Units

As of June 30, 2022, there were 1,800,000 of our 9.625% 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 June 30, 2022, we did not declare or pay distributions to the holders of the Class C Preferred Units, thus the quarterly distribution for June 30, 2022 is $0.6016 and the cumulative distribution since suspension for each Class C Preferred Unit is $3.6094. 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 June 30, 2022 is $6.9 million.

Class D Preferred Units

As of June 30, 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 is 9.00% per year per unit (equal to $90.00 per every $1,000 in unit value per year), plus an additional 1.5% 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 and restated limited partnership agreement. For the quarter ended June 30, 2022, we did not declare or pay distributions to the holders of the Class D Preferred Units, thus the average quarterly distribution at June 30, 2022 is $27.32 and the average cumulative distribution since suspension for each Class D Preferred unit is $162.60. 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 June 30, 2022 is $103.9 million.

On July 1, 2022, the current distribution rate for the Class D Preferred Units increased to 10.00% per year per unit, plus an additional 1.5% rate increase due to us exceeding the adjusted total leverage ratio and due to a Class D distribution payment default, as described above.

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 three months ended June 30, 2022:

		Weighted-Average
		Grant Date
	Number of	Fair Value
	Units	Per Unit
Unvested Service Award units at March 31, 2022	2,188,800	$2.15
Units forfeited	(49,500)	$2.15
Unvested Service Award units at June 30, 2022	2,139,300	$2.15

As the LTIP expired on May 10, 2021, we had no common units available for grant for the three months ended June 30, 2022.

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

As of June 30, 2022, there are 1,426,075 unvested Service Award units which are expected to vest during the year ending March 31, 2023 and 713,225 unvested Service Award units which are expected to vest during the 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 June 30, 2022 and 2021, we recorded compensation expense related to Service Award units of $0.5 million and $1.0 million, respectively.

For the unvested Service Award units, as of June 30, 2022, we had estimated future expense of $2.7 million which we expect to record during the year ending March 31, 2023 and $1.3 million which we expect to record during the 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.

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:

	June 30, 2022				March 31, 2022
	Derivative<br>Assets		Derivative<br>Liabilities		Derivative<br>Assets		Derivative<br>Liabilities
	(in thousands)
Level 1 measurements	$	84,318	$	(8,406)	$	73,353	$	(47,585)
Level 2 measurements	40,398		(23,246)		51,968		(27,372)
	124,716		(31,652)		125,321		(74,957)
Netting of counterparty contracts (1)	(8,659)		8,659		(47,585)		47,585
Net cash collateral (held) provided	(58,787)		(326)		839		—
Commodity derivatives	$	57,270	$	(23,319)	$	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:

	June 30, 2022		March 31, 2022
	(in thousands)
Prepaid expenses and other current assets	$	57,270	$	78,575
Accrued expenses and other payables	(23,013)		(27,108)
Other noncurrent liabilities	(306)		(264)
Net commodity derivative asset	$	33,951	$	51,203

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<br>(Short)<br>Notional Units<br>(in barrels)	Fair Value<br>of<br>Net Assets<br>(Liabilities)
		(in thousands)
At June 30, 2022:
Crude oil fixed-price (1)	July 2022–December 2023	(567)	$	76,370
Propane fixed-price (1)	July 2022–March 2024	1,325	2,982
Refined products fixed-price (1)	July 2022–January 2023	(147)	(1,525)
Butane fixed-price (1)	July 2022–December 2023	(400)	630
Other	July 2022–August 2024		14,607
			93,064
Net cash collateral held			(59,113)
Net commodity derivative asset			$	33,951
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 June 30, 2022 and 2021, we recorded net losses of $41.1 million and $56.7 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 June 30, 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 Wall Street Journal prime rate or LIBOR interest rate (or successor rate, which has since been determined to be SOFR). At June 30, 2022, we had $171.0 million of outstanding borrowings under the ABL Facility at a weighted average interest rate of 4.84%.

In addition, on and after certain dates, distributions for our Class B Preferred Units and Class C Preferred Units will be calculated using the applicable three-month LIBOR interest rate (or alternative rate as determined in accordance with the partnership agreement) plus a spread (see Note 8 for a further discussion). On and after a certain date, the holders of the Class D Preferred Units can elect, from time to time, for the distributions to be calculated based on the applicable three-month LIBOR interest rate (or alternative rate as determined in accordance with the partnership agreement) plus a spread (“Class D Variable

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

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 June 30, 2022 (in thousands):

Senior Secured Notes:
2026 Senior Secured Notes	$	1,843,292
Senior Unsecured Notes:
2023 Notes	$	409,837
2025 Notes	$	286,282
2026 Notes	$	241,130

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:

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Revenues:
Water Solutions:
Topic 606 revenues
Disposal service fees	$	117,226	$	98,297
Sale of recovered crude oil	38,449		13,801
Sale of water	5,808		13,282
Other service revenues	4,596		4,846
Total Water Solutions revenues	166,079		130,226
Crude Oil Logistics:
Topic 606 revenues
Crude oil sales	847,776		535,429
Crude oil transportation and other	20,595		18,449
Non-Topic 606 revenues	1,859		2,245
Elimination of intersegment sales	(4,859)		(2,499)
Total Crude Oil Logistics revenues	865,371		553,624
Liquids Logistics:
Topic 606 revenues
Refined products	748,631		393,109
Propane sales	221,795		160,403
Butane sales	200,476		118,540
Other product sales	154,342		114,330
Service revenues	2,982		5,423
Non-Topic 606 revenues	137,707		14,307
Elimination of intersegment sales	—		(1,307)
Total Liquids Logistics revenues	1,465,933		804,805
Total revenues	$	2,497,383	$	1,488,655

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 June 30,
	2022		2021
	(in thousands)
Depreciation and Amortization:
Water Solutions	$	49,910	$	63,043
Crude Oil Logistics	11,754		12,409
Liquids Logistics	3,449		7,045
Corporate and Other	5,855		5,484
Total	$	70,968	$	87,981
Operating Income (Loss):
Water Solutions	$	53,605	$	7,583
Crude Oil Logistics	18,989		(11,581)
Liquids Logistics	26,640		(53,409)
Corporate and Other	(11,971)		(11,927)
Total	$	87,263	$	(69,334)

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 June 30,
	2022		2021
	(in thousands)
Water Solutions	$	40,835	$	26,962
Crude Oil Logistics	4,133		463
Liquids Logistics	1,386		3,544
Corporate and Other	367		911
Total	$	46,721	$	31,880

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

	June 30, 2022		March 31, 2022
	(in thousands)
Long-lived assets, net:
Water Solutions	$	2,954,908	$	2,970,911
Crude Oil Logistics	1,043,189		1,050,546
Liquids Logistics (1)	378,150		385,783
Corporate and Other	47,070		49,067
Total	$	4,423,317	$	4,456,307

(1)    Includes $17.5 million and $17.1 million of non-US long-lived assets at June 30, 2022 and March 31, 2022, respectively.

	June 30, 2022		March 31, 2022
	(in thousands)
Total assets:
Water Solutions	$	3,127,295	$	3,130,659
Crude Oil Logistics	2,083,458		1,952,048
Liquids Logistics (1)	977,418		888,927
Corporate and Other	49,387		98,711
Total	$	6,237,558	$	6,070,345

(1)    Includes $65.5 million and $40.2 million of non-US total assets at June 30, 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 June 30,
	2022		2021
	(in thousands)
Purchases from entities affiliated with management	$	—	$	70
Purchases from equity method investees	$	498	$	191

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

	June 30, 2022		March 31, 2022
	(in thousands)
NGL Energy Holdings LLC	$	8,847	$	8,483
Equity method investees	390		107
Entities affiliated with management	1		1
Total	$	9,238	$	8,591

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:

	June 30, 2022		March 31, 2022
	(in thousands)
Equity method investees	$	90	$	27
Entities affiliated with management	1		46
Total	$	91	$	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 June 30, 2022, the outstanding balance of the loan is approximately $2.5 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 June 30, 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 scope under 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 June 30, 2022.

The majority of our revenue agreements are within scope under ASC 606 and the remainder of our revenue comes from contracts that are accounted for as derivatives under ASC 815 or that contain nonmonetary exchanges or leases and are in scope under Topics 845 and 842, respectively. See Note 10 for a detail of disaggregated revenue. Revenue from contracts accounted for as derivatives under ASC 815 within our Liquids Logistics segment includes $5.1 million of net losses related to changes in the mark-to-market value of these arrangements recorded during the three months ended June 30, 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 June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	114,830
2024	105,297
2025	73,235
2026	17,240
2027	3,727
2028	1,269
Thereafter	803
Total	$	316,401

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:

	June 30, 2022		March 31, 2022
	(in thousands)
Accounts receivable from contracts with customers	$	590,488	$	605,384
Contract assets (current)	$	1,467	$	—
Contract liabilities balance at March 31, 2022	$	7,667
---	---	---
Payment received and deferred	27,799
Payment recognized in revenue	(13,819)
Contract liabilities balance at June 30, 2022	$	21,647

Note 13—Leases

Lessee Accounting

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

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

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Operating lease expense	$	13,678	$	15,274
Variable lease expense	7,028		5,230
Short-term lease expense	94		70
Total	$	20,800	$	20,574

The following table summarizes maturities of our operating lease obligations at June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	35,135
2024	31,997
2025	19,206
2026	8,446
2027	4,596
2028	4,405
Thereafter	34,416
Total lease payments	138,201
Less imputed interest	(30,571)
Total operating lease obligations	$	107,630

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

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Cash paid for amounts included in the measurement of operating lease obligations	$	13,031	$	14,554
Operating lease right-of-use assets obtained in exchange for operating lease obligations	$	5,920	$	7,312

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.

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

During the three months ended June 30, 2022 and 2021, fixed rental revenue was $3.5 million, which includes $0.2 million of sublease revenue, and $3.3 million, which includes $0.4 million of sublease revenue, respectively.

The following table summarizes future minimum lease payments receivable under various noncancelable operating lease agreements at June 30, 2022 (in thousands):

Fiscal Year Ending March 31,
2023 (nine months)	$	8,089
2024	4,926
2025	692
2026	415
2027	415
2028	415
Thereafter	189
Total	$	15,141

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. We manage receivable pools using past due balances as a key credit quality indicator.

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	(1)		(418)
Balance at June 30, 2022	$	2,625	$	40

Note 15—Other Matters

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. As of 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

During July 2022, we repurchased $14.2 million of the 2023 Notes and $1.5 million of the 2026 Notes.

NGL ENERGY PARTNERS LP AND SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements (Continued)

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 ended June 30, 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 June 30, 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

The COVID-19 pandemic, including the outbreak of several variants, has caused continued volatility in commodity prices due to, among other things, reduced industrial activity and travel demand, varying worldwide restrictions and the timing of closing and re-opening of economies throughout the last two years. The unprecedented restrictions on travel and economic activity during the early stages of the COVID-19 pandemic significantly reduced demand for refined products. The lingering impact of the COVID-19 pandemic continues to ripple through the United States economy, most notably in the form of rising inflation and supply chain issues. Additionally, the Russian invasion of Ukraine beginning in February 2022 and the ongoing war has caused additional volatility in commodity prices on worldwide supply constraints and has seemed to have only amplified inflation and supply chain constraints in the United States.

While we have seen continued recovery in commodity prices since the beginning of the pandemic, primarily due to economies re-opening over time and the reduction in oil and natural gas supply resulting from the war in Ukraine, there is still an element of volatility that we expect to continue due to the uncertainty of the COVID-19 pandemic and the war in Ukraine. This volatility could negatively impact commodity prices or rising inflation could impact demand for refined products. Given the uncertain timing of a return of refined product demand to historical levels, the extent these events will have an impact on our results of operations is unclear.

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 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 affected areas, the diverse locations of our disposal facilities, and the connectivity of our system, we have not been negatively impacted by these actions.

Table of Contents

Consolidated Results of Operations

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

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Revenues	$	2,497,383	$	1,488,655
Cost of sales	2,255,011		1,324,793
Operating expenses	71,860		65,784
General and administrative expense	16,757		15,774
Depreciation and amortization	66,660		84,102
(Gain) loss on disposal or impairment of assets, net	(168)		67,536
Operating income (loss)	87,263		(69,334)
Equity in earnings of unconsolidated entities	674		212
Interest expense	(67,311)		(67,130)
Gain on early extinguishment of liabilities, net	1,662		51
Other income, net	646		1,249
Income (loss) before income taxes	22,934		(134,952)
Income tax benefit	172		450
Net income (loss)	23,106		(134,502)
Less: Net income attributable to noncontrolling interests	(245)		(438)
Net income (loss) attributable to NGL Energy Partners LP	$	22,861	$	(134,940)

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 ended June 30, 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 June 30, 2022, we repurchased $23.3 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.

•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 June 30, 2022.

Table of Contents

Segment Operating Results for the Three Months Ended June 30, 2022 and 2021

Water Solutions

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

	Three Months Ended June 30,
	2022		2021		Change
	(in thousands, except per barrel and per day amounts)
Revenues:
Water disposal service fees	$	113,883	$	94,728	$	19,155
Sale of recovered crude oil	38,449		13,801		24,648
Recycled water	4,410		3,202		1,208
Other revenues	9,337		18,495		(9,158)
Total revenues	166,079		130,226		35,853
Expenses:
Cost of sales-excluding impact of derivatives	4,818		8,965		(4,147)
Derivative loss	5,407		1,373		4,034
Operating expenses	48,197		40,025		8,172
General and administrative expenses	3,263		1,808		1,455
Depreciation and amortization expense	49,848		62,981		(13,133)
Loss on disposal or impairment of assets, net	941		7,491		(6,550)
Total expenses	112,474		122,643		(10,169)
Segment operating income	$	53,605	$	7,583	$	46,022
Produced water processed (barrels per day)
Delaware Basin	1,887,230		1,428,222		459,008
Eagle Ford Basin	98,513		91,843		6,670
DJ Basin	150,329		118,801		31,528
Other Basins	17,886		28,082		(10,196)
Total	2,153,958		1,666,948		487,010
Recycled water (barrels per day)	136,925		109,437		27,488
Total (barrels per day)	2,290,883		1,776,385		514,498
Skim oil sold (barrels per day)	3,957		2,500		1,457
Service fees for produced water processed ($/barrel) (1)	$	0.58	$	0.62	$	(0.04)
Recovered crude oil for produced water processed ($/barrel) (1)	$	0.20	$	0.09	$	0.11
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 June 30, 2022 and 2021 were 196,010,195 and 151,692,287, 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 sold due to increased produced water processed as well as higher crude oil prices realized. 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. 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.

Table of Contents

Other Revenues. Other revenues primarily include brackish non-potable water revenues, water pipeline revenues, land surface use revenues and solids disposal 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.

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 June 30, 2022, we had $0.1 million of net unrealized gains on derivatives and $5.5 million of net realized losses on derivatives. At June 30, 2022, we had approximately 2,000 barrels per day hedged in a swap transaction for the next three months at an average price of $85.50 per barrel. We closed these positions in July 2022, and recorded a loss of $3.3 million. During the three months ended June 30, 2021, we had $2.2 million of net realized gains on derivatives and $3.6 million of net unrealized losses 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 negotiating long-term utility contracts with fixed rates, royalty contracts with no escalation clauses and a fixed chemical expense per barrel with our chemical provider. Severance taxes also increased 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 three months ended June 30, 2022. These decreases were partially offset by the depreciation of newly developed facilities and infrastructure.

Loss on Disposal or Impairment of Assets, Net. During the three months ended June 30, 2022, we recorded a loss of $0.5 million related to the sale of certain assets as part of the termination of a joint marketing agreement and a net loss of $0.5 million primarily related to the abandonment of certain capital projects and the sale and retirement of certain other miscellaneous assets. During the three months ended June 30, 2021, we recorded a net loss of $7.5 million primarily related to facilities damaged by lightning strikes, abandonment of certain capital projects and the sale of certain other miscellaneous assets.

Table of Contents

Crude Oil Logistics

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

	Three Months Ended June 30,
	2022		2021		Change
	(in thousands, except per barrel amounts)
Revenues:
Crude oil sales	$	847,776	$	535,429	$	312,347
Crude oil transportation and other	22,454		20,694		1,760
Total revenues (1)	870,230		556,123		314,107
Expenses:
Cost of sales-excluding impact of derivatives	801,362		501,462		299,900
Derivative loss	25,867		38,294		(12,427)
Operating expenses	12,188		13,587		(1,399)
General and administrative expenses	1,330		1,994		(664)
Depreciation and amortization expense	11,754		12,409		(655)
Gain on disposal or impairment of assets, net	(1,260)		(42)		(1,218)
Total expenses	851,241		567,704		283,537
Segment operating income (loss)	$	18,989	$	(11,581)	$	30,570
Crude oil sold (barrels)	7,634		7,994		(360)
Crude oil transported on owned pipelines (barrels)	7,170		7,034		136
Crude oil storage capacity - owned and leased (barrels) (2)	5,232		5,239		(7)
Crude oil storage capacity leased to third parties (barrels) (2)	1,501		1,501		—
Crude oil inventory (barrels) (2)	855		1,147		(292)
Crude oil sold ($/barrel)	$	111.053	$	66.979	$	44.074
Cost per crude oil sold ($/barrel) (3)	$	104.973	$	62.730	$	42.243
Crude oil product margin ($/barrel) (3)	$	6.080	$	4.249	$	1.831

(1)    Revenues include $4.9 million and $2.5 million of intersegment sales during the three months ended June 30, 2022 and 2021, respectively, that are eliminated in our unaudited condensed consolidated statements of operations.

(2)    Information is presented as of June 30, 2022 and June 30, 2021, respectively.

(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 three months ended June 30, 2022, compared to the three months ended June 30, 2021. This was offset by a reduction in sales volumes. We had an increase in buy/sell transactions during the quarter ended June 30, 2022. These are transactions in which we transact to 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.

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 June 30, 2022, physical volumes on the Grand Mesa Pipeline averaged approximately 79,000 barrels per day, compared to approximately 77,000 barrels per day for the three months ended June 30, 2021 (volume amounts are from both internal and external parties).

Cost of Sales-Excluding Impact of Derivatives. The increase was due primarily to an increase in crude oil prices during the three months ended June 30, 2022, compared to the three months ended June 30, 2021.

Derivative Loss. Our cost of sales during the three months ended June 30, 2022 included $76.9 million of net realized losses on derivatives, driven by increasing crude oil prices, partially offset by $51.0 million of net unrealized gains on derivatives. The amounts for the quarter ended June 30, 2022 include net realized losses of $46.3 million and net unrealized gains of $29.5 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 June 30, 2021 included $52.7 million of net realized losses on derivatives, driven by the increase in crude oil prices offset by $14.5 million of

Table of Contents

net unrealized gains on derivatives. The amounts for the quarter ended June 30, 2021 include net realized losses of $25.5 million and net unrealized gains of $13.4 million associated with derivative instruments related to our hedge of the CMA Differential Roll.

Crude Oil Product Margin. The increase was primarily due to higher crude oil prices as contracted rates with certain producers increased due to higher crude oil prices, as well as increased differentials on certain other sales contracts, offset by higher trucking expenses.

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.

Gain on Disposal or Impairment of Assets, Net. During the three months ended June 30, 2022, we recorded a net gain of $1.3 million primarily due to the sale of land, which was previously used by our trucking business, and the sale of certain other equipment, offset by the write-off of equipment and software previously utilized by, but not sold with our trucking business. During the three months ended June 30, 2021, we recorded a net gain of less than $0.1 million due to the disposal of certain assets.

Table of Contents

Liquids Logistics

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

	Three Months Ended June 30,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Refined products sales:
Revenues-excluding impact of derivatives (1)	$	748,679	$	393,147	$	355,532
Cost of sales-excluding impact of derivatives	738,074		389,571		348,503
Derivative loss	1,052		695		357
Product margin	9,553		2,881		6,672
Propane sales:
Revenues (1)	222,574		160,890		61,684
Cost of sales-excluding impact of derivatives	212,289		156,527		55,762
Derivative gain	(1,932)		(10,115)		8,183
Product margin	12,217		14,478		(2,261)
Butane sales:
Revenues (1)	200,594		118,519		82,075
Cost of sales-excluding impact of derivatives	200,219		114,410		85,809
Derivative (gain) loss	(8,132)		7,684		(15,816)
Product margin (loss)	8,507		(3,575)		12,082
Other product sales:
Revenues-excluding impact of derivatives (1)	295,006		134,815		160,191
Cost of sales-excluding impact of derivatives	266,752		109,176		157,576
Derivative loss	18,805		18,726		79
Product margin	9,449		6,913		2,536
Service revenues:
Revenues (1)	4,138		7,270		(3,132)
Cost of sales	347		360		(13)
Product margin	3,791		6,910		(3,119)
Expenses:
Operating expenses	11,475		12,172		(697)
General and administrative expenses	2,021		1,790		231
Depreciation and amortization expense	3,381		6,967		(3,586)
Loss on disposal or impairment of assets, net	—		60,087		(60,087)
Total expenses	16,877		81,016		(64,139)
Segment operating income (loss)	$	26,640	$	(53,409)	$	80,049

Table of Contents

	Three Months Ended June 30,
	2022		2021		Change
	(in thousands, except per gallon amounts)
Natural gas liquids and refined products storage capacity - owned and leased (gallons) (2)	167,559		168,677		(1,118)
Refined products sold (gallons)	188,626		185,306		3,320
Refined products sold ($/gallon)	$	3.969	$	2.122	$	1.847
Cost per refined products sold ($/gallon) (3)	$	3.913	$	2.102	$	1.811
Refined products product margin ($/gallon) (3)	$	0.056	$	0.020	$	0.036
Refined products inventory (gallons) (2)	1,110		2,776		(1,666)
Propane sold (gallons)	164,844		170,279		(5,435)
Propane sold ($/gallon)	$	1.350	$	0.945	$	0.405
Cost per propane sold ($/gallon) (3)	$	1.288	$	0.919	$	0.369
Propane product margin ($/gallon) (3)	$	0.062	$	0.026	$	0.036
Propane inventory (gallons) (2)	63,862		60,673		3,189
Butane sold (gallons)	120,525		122,574		(2,049)
Butane sold ($/gallon)	$	1.664	$	0.967	$	0.697
Cost per butane sold ($/gallon) (3)	$	1.661	$	0.933	$	0.728
Butane product margin ($/gallon) (3)	$	0.003	$	0.034	$	(0.031)
Butane inventory (gallons) (2)	49,547		45,911		3,636
Other products sold (gallons)	93,637		92,853		784
Other products sold ($/gallon)	$	3.151	$	1.452	$	1.699
Cost per other products sold ($/gallon) (3)	$	2.849	$	1.176	$	1.673
Other products product margin ($/gallon) (3)	$	0.302	$	0.276	$	0.026
Other products inventory (gallons) (2)	28,187		40,691		(12,504)

(1)    Revenue includes $1.3 million of intersegment sales during the three months ended June 30, 2021 that is eliminated in our unaudited condensed consolidated statement of operations.

(2)    Information is presented as of June 30, 2022 and June 30, 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 and an increase in volumes. The increase in volumes is due to the continued recovery of demand from the COVID-19 pandemic, as we continue to work on increasing our allocations from certain suppliers that were reduced due to the COVID-19 pandemic. The increase in volumes was partially offset by tighter supply in certain markets.

Refined Products Derivative Loss. Our refined products margin during the three months ended June 30, 2022 included a realized loss of $1.1 million and the three months ended June 30, 2021 included a realized loss of $0.7 million.

Refined Products product margins increased during the three months ended June 30, 2022 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 increases in revenues and cost of sales were due to higher commodity prices. The increase in propane prices was the result of the overall strength in crude oil and natural gas prices. This was partially offset by reduced volumes as we tapered purchases of propane during the three months ended June 30, 2022 compared to the three months ended June 30, 2021 as a result of weaker demand in the market due to the higher prices.

Propane Derivative Gain. Our cost of propane sales during the three months ended June 30, 2022 included a net unrealized gain of less than $0.1 million on derivatives and $1.9 million of net realized gains on derivatives. During the three months ended June 30, 2021, our cost of wholesale propane sales included $11.9 million of net unrealized gains on derivatives and $1.8 million of net realized losses on derivatives.

Propane product margins, excluding the impact of derivatives, increased due to reducing the value of our inventory to

Table of Contents

its lower of cost or realizable value as of March 31, 2022 and due to a reduction in storage and railcar costs.

Butane Sales and Cost of Sales-Excluding Impact of Derivatives. The increases in revenues and cost of sales were primarily due to an increase in commodity prices, which was the result of the overall strength in crude oil and natural gas prices and increased global demand. The increase was partially offset by slightly lower volumes.

Butane Derivative (Gain) Loss. Our cost of butane sales during the three months ended June 30, 2022 included $6.1 million of net unrealized gains on derivatives and $2.1 million of net realized gains on derivatives. Our cost of butane sales included $6.5 million of net unrealized losses on derivatives and $1.2 million of net realized losses on derivatives during the three months ended June 30, 2021.

Butane product margins, excluding the impact of derivatives, decreased due to lower location differentials. Butane we contracted for purchase at the beginning of the season (February and March 2022) was competing with product purchased in the currently discounted market, resulting in our product being more expensive, which reduced margins.

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 as a result of the overall strength in crude oil and natural gas prices. In addition, we had an increased supply of biodiesel to sell during the three months ended June 30, 2022 as compared to the three months ended June 30, 2021 due to favorable supply contracts entered into in the prior year.

Other Products Derivative Loss. Our derivatives of other products included $0.3 million of net unrealized losses and $18.5 million of net realized losses on derivatives during the three months ended June 30, 2022. Our derivatives of other products during the three months ended June 30, 2021 included $18.7 million of net realized losses on derivatives.

Other product sales product margins during the three months ended June 30, 2022 increased from the prior year primarily due to the increase in biodiesel volumes, as discussed above.

Service Revenues. This revenue includes storage, terminaling and transportation services income. The decrease for the current quarter was due primarily to the disposition of Sawtooth in June 2021.

Operating and General and Administrative Expenses. The decrease was primarily due to the disposition of Sawtooth in June 2021 which was offset by higher incentive compensation and increased travel and entertainment as a result of increased sales calling efforts following the pandemic.

Depreciation and Amortization Expense. The decrease was primarily due to the disposition of Sawtooth in June 2021 and lower amortization expense due to certain intangible assets being fully amortized as of September 30, 2021.

Loss on Disposal or Impairment of Assets, Net. During the three months ended June 30, 2021, we recorded a net loss of $60.1 million related to the sale of Sawtooth.

Corporate and Other

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

	Three Months Ended June 30,
	2022		2021		Change
	(in thousands)
Expenses:
General and administrative expenses	$	10,143	$	10,182	$	(39)
Depreciation and amortization expense	1,677		1,745		(68)
Loss on disposal or impairment of assets, net	151		—		151
Total expenses	11,971		11,927		44
Operating loss	$	(11,971)	$	(11,927)	$	(44)

General and Administrative Expenses. The expenses during the three months ended June 30, 2022 were consistent with the three months ended June 30, 2021.

Depreciation and Amortization Expense. Depreciation and amortization expense during the three months ended

Table of Contents

June 30, 2022 was consistent with the three months ended June 30, 2021.

Loss on Disposal or Impairment of Assets, Net. During the three months ended June 30, 2022, we received a prepayment of a loan receivable due July 31, 2023, and in exchange for the prepayment we reduced the amount of the final payment and recorded a loss for the reduction in the amount due.

Equity in Earnings of Unconsolidated Entities

Equity in earnings of unconsolidated entities was $0.7 million during the three months ended June 30, 2022, compared to $0.2 million during the three months ended June 30, 2021. The increase of $0.5 million during the three months ended June 30, 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 June 30,
	2022		2021		Change
	(in thousands)
Senior secured notes	$	38,438	$	38,438	$	—
Senior unsecured notes	20,819		22,529		(1,710)
Revolving credit facility	3,240		1,822		1,418
Other indebtedness	636		597		39
Total debt interest expense	63,133		63,386		(253)
Amortization of debt issuance costs	4,178		3,744		434
Total interest expense	$	67,311	$	67,130	$	181

The increase of $0.2 million during the three months ended June 30, 2022 was primarily due to an increase of the revolving credit facility balance which was offset by repurchases of a portion of our 2023 Notes.

Gain on Early Extinguishment of Liabilities, Net

Gain on early extinguishment of liabilities, net was $1.7 million during the three months ended June 30, 2022, compared to $0.1 million during the three months ended June 30, 2021. During the three months ended June 30, 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. For the three months ended June 30, 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

Other income, net was $0.6 million during the three months ended June 30, 2022, compared to $1.2 million during the three months ended June 30, 2021. The decrease of $0.6 million during the three months ended June 30, 2022 was primarily due to the reversal of an obligation assumed in an acquisition that closed in fiscal year 2020.

Income Tax Benefit

Income tax benefit was $0.2 million during the three months ended June 30, 2022, compared to an income tax benefit of $0.5 million during the three months ended June 30, 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 $0.2 million during the three months ended June 30, 2022, compared to $0.4 million during the three months ended June 30, 2021, which included a loss of $0.2 million from the operations of Sawtooth. The decrease

Table of Contents

during the three months ended June 30, 2022 was due primarily to lower income from certain recycling operations and water solutions operations during the three months ended June 30, 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 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.

Table of Contents

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

	Three Months Ended June 30,
	2022		2021
	(in thousands)
Net income (loss)	$	23,106	$	(134,502)
Less: Net income attributable to noncontrolling interests	(245)		(438)
Net income (loss) attributable to NGL Energy Partners LP	22,861		(134,940)
Interest expense	67,326		67,130
Income tax benefit	(172)		(450)
Depreciation and amortization	66,614		83,357
EBITDA	156,629		15,097
Net unrealized gains on derivatives	(56,902)		(16,264)
CMA Differential Roll net losses (gains) (1)	34,620		24,310
Inventory valuation adjustment (2)	(555)		1,218
Lower of cost or net realizable value adjustments	(9,286)		(3,806)
(Gain) loss on disposal or impairment of assets, net	(168)		67,538
Gain on early extinguishment of liabilities, net	(1,662)		(87)
Equity-based compensation expense	497		960
Acquisition expense (3)	—		67
Other (4)	703		2,068
Adjusted EBITDA	$	123,876	$	91,101

(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 and accretion expense for asset retirement obligations.

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 June 30,
	2022		2021
	(in thousands)
Depreciation and amortization per EBITDA table	$	66,614	$	83,357
Intangible asset amortization recorded to cost of sales	(68)		(73)
Depreciation and amortization of unconsolidated entities	(170)		(166)
Depreciation and amortization attributable to noncontrolling interests	284		984
Depreciation and amortization per unaudited condensed consolidated statements of operations	$	66,660	$	84,102
	Three Months Ended June 30,
---	---	---	---	---
	2022		2021
	(in thousands)
Depreciation and amortization per EBITDA table	$	66,614	$	83,357
Amortization of debt issuance costs recorded to interest expense	4,178		3,744
Amortization of royalty expense recorded to operating expense	62		62
Depreciation and amortization of unconsolidated entities	(170)		(166)
Depreciation and amortization attributable to noncontrolling interests	284		984
Depreciation and amortization per unaudited condensed consolidated statements of cash flows	$	70,968	$	87,981

Table of Contents

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 June 30,
	2022		2021
	(in thousands)
Interest expense per EBITDA table	$	67,326	$	67,130
Interest expense attributable to unconsolidated entities	(15)		(17)
Interest expense attributable to noncontrolling interests	—		17
Interest expense per unaudited condensed consolidated statements of operations	$	67,311	$	67,130

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

	Three Months Ended June 30, 2022
	Water<br>Solutions		Crude Oil<br>Logistics		Liquids<br>Logistics		Corporate<br>and Other		Consolidated
	(in thousands)
Operating income (loss)	$	53,605	$	18,989	$	26,640	$	(11,971)	$	87,263
Depreciation and amortization	49,848		11,754		3,381		1,677		66,660
Amortization recorded to cost of sales	—		—		68		—		68
Net unrealized gains on derivatives	(124)		(51,005)		(5,773)		—		(56,902)
CMA Differential Roll net losses (gains)	—		34,620		—		—		34,620
Inventory valuation adjustment	—		—		(555)		—		(555)
Lower of cost or net realizable value adjustments	—		1,567		(10,853)		—		(9,286)
Loss (gain) on disposal or impairment of assets, net	941		(1,260)		—		151		(168)
Equity-based compensation expense	—		—		—		497		497
Other income (expense), net	259		28		(93)		452		646
Adjusted EBITDA attributable to unconsolidated entities	825		—		(7)		44		862
Adjusted EBITDA attributable to noncontrolling interest	(532)		—		—		—		(532)
Other	225		385		93		—		703
Adjusted EBITDA	$	105,047	$	15,078	$	12,901	$	(9,150)	$	123,876			Three Months Ended June 30, 2021
---	---	---	---	---	---	---	---	---	---	---
	Water<br>Solutions		Crude Oil<br>Logistics		Liquids<br>Logistics		Corporate<br>and Other		Consolidated
	(in thousands)
Operating income (loss)	$	7,583	$	(11,581)	$	(53,409)	$	(11,927)	$	(69,334)
Depreciation and amortization	62,981		12,409		6,967		1,745		84,102
Amortization recorded to cost of sales	—		—		73		—		73
Net unrealized losses (gains) on derivatives	3,566		(14,454)		(5,376)		—		(16,264)
CMA Differential Roll net losses (gains)	—		24,310		—		—		24,310
Inventory valuation adjustment	—		—		1,218		—		1,218
Lower of cost or net realizable value adjustments	—		(11)		(3,795)		—		(3,806)
Loss (gain) on disposal or impairment of assets, net	7,491		(42)		60,087		—		67,536
Equity-based compensation expense	—		—		—		960		960
Acquisition expense	—		—		—		67		67
Other income, net	612		196		363		78		1,249
Adjusted EBITDA attributable to unconsolidated entities	459		—		(10)		(55)		394
Adjusted EBITDA attributable to noncontrolling interest	(954)		—		(529)		—		(1,483)
Other	(227)		2,321		(15)		—		2,079
Adjusted EBITDA	$	81,511	$	13,148	$	5,574	$	(9,132)	$	91,101

Table of Contents

Liquidity, Sources of Capital and Capital Resource Activities

General

Our principal sources of liquidity and capital resource requirements are the 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. 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 borrowings also increase due to rising 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 $600.0 million ABL Facility, which we believe will provide liquidity to operate our business and manage our working capital requirements. As part of our amended ABL Facility, 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 June 30, 2022, $171.0 million had been borrowed under the ABL Facility and we had letters of credit outstanding of approximately $143.6 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.

As of June 30, 2022, our current assets exceeded our current liabilities by approximately $356.9 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, 6.125% senior unsecured notes due 2025 and 7.5% senior unsecured notes due 2026 (collectively, the “Senior Unsecured Notes”).

Table of Contents

Repurchases

During the three months ended June 30, 2022, we repurchased $23.3 million of the 2023 Notes at a cash cost of $21.5 million (excluding payment of accrued 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.

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 June 30,
2022	$	31,354	$	15,367	$	—	$	—
2021	$	24,135	$	7,745	$	—	$	116

(1)    There were no acquisitions during the three months ended June 30, 2022 or 2021.

(2)    Amount for the three months ended June 30, 2021 relates to contributions made to unconsolidated entities. There were no other investments for the three months ended June 30, 2022.

Capital expenditures for the fiscal year ending March 31, 2023 are expected to be approximately $100 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, operating 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.

Table of Contents

Cash Flows

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

	Three Months Ended June 30,
Cash Flows Provided by (Used in):	2022		2021
	(in thousands)
Operating activities, before changes in operating assets and liabilities	$	139,586	$	80,288
Changes in operating assets and liabilities	(137,100)		(85,451)
Operating activities	$	2,486	$	(5,163)
Investing activities	$	(36,422)	$	(42,875)
Financing activities	$	30,930	$	45,680

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 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 three months ended June 30, 2022 was due primarily to increased earnings from operations and fluctuations in the value of accounts receivable, accounts payable and inventories during the three months ended June 30, 2022.

Investing Activities. Net cash used in investing activities was $36.4 million during the three months ended June 30, 2022, compared to net cash used in investing activities of $42.9 million during the three months ended June 30, 2021. The decrease in net cash used in investing activities was due primarily to:

•a $57.6 million decrease in payments to settle derivatives;

•proceeds of $6.9 million from certain asset sales during the three months ended June 30, 2022; and

•a decrease in capital expenditures from $46.8 million (includes payment of amounts accrued as of March 31, 2021) during the three months ended June 30, 2021 to $41.0 million (includes payment of amounts accrued as of March 31, 2022) during the three months ended June 30, 2022 due primarily to fewer expansion projects in our Water Solutions segment.

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.

Financing Activities. Net cash provided by financing activities was $30.9 million during the three months ended June 30, 2022, compared to net cash provided by financing activities of $45.7 million during the three months ended June 30, 2021. The decrease in net cash provided by financing activities was due primarily to:

•a decrease of $18.0 million in borrowings on the revolving credit facility (net of repayments) during the three months ended June 30, 2022; and

•an increase of $3.1 million paid in cash to repurchase a portion of our senior unsecured notes during the three months ended June 30, 2022.

These decreases in net cash provided by financing activities were partially offset by 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 on June 18, 2021.

Table of Contents

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-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

Table of Contents

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 Wall Street Journal prime rate or SOFR, an adjusted forward-looking term rate based on the secured overnight financing rate. At June 30, 2022, we had $171.0 million of outstanding borrowings under the ABL Facility at a weighted average interest rate of 4.84%. A change in interest 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 June 30, 2022.

In addition, on and after certain dates, distributions for our Class B Preferred Units and Class C Preferred Units will be calculated using the applicable three-month LIBOR interest rate (or alternative rate as determined in the partnership agreement) plus a spread. For our Class B Preferred Units, distributions on and after July 1, 2022 began accumulating 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 7.213%. 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.

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.

Table of Contents

The following table summarizes the hypothetical impact on the June 30, 2022 fair value of our commodity derivatives of an increase of 10% in the value of the underlying commodity (in thousands):

	Increase<br>(Decrease)<br>To Fair Value
Crude oil (Water Solutions segment)	$	(1,880)
Crude oil (Crude Oil Logistics segment)	$	(3,106)
Propane (Liquids Logistics segment)	$	6,312
Butane (Liquids Logistics segment)	$	(5,654)
Refined Products (Liquids Logistics segment)	$	(1,997)
Other Products (Liquids Logistics segment)	$	482
Canadian dollars (Liquids Logistics segment)	$	161

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.

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 June 30, 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 June 30, 2022. Based on this evaluation, the principal executive officer and principal

Table of Contents

financial officer of our general partner have concluded that as of June 30, 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 June 30, 2022 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

Table of Contents

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

Not applicable.

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.

Table of Contents

Item 6.    Exhibits

Exhibit Number	Exhibit
10.1	SecondAmendment to Credit Agreement (incorporated by reference to Exhibit 10.3to theAnnualReport on Form 10-K(File No. 001-35172) for theyearendedMarch31, 2022filed with the SEC onJunehttp://www.sec.gov/Archives/edgar/data/1504461/000150446122000010/ex10303312210-k.htm6, 2022)
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 June 30, 2022 and March 31, 2022, (ii) Unaudited Condensed Consolidated Statements of Operations for the three months ended June 30, 2022 and 2021, (iii) Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss) for the three months ended June 30, 2022 and 2021, (iv) Unaudited Condensed Consolidated Statements of Changes in Equity for the three months ended June 30, 2022 and 2021, (v) Unaudited Condensed Consolidated Statements of Cash Flows for the three months ended June 30, 2022 and 2021, and (vi) Notes to Unaudited Condensed Consolidated Financial Statements.

Table of Contents

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: August 9, 2022		By:	/s/ H. Michael Krimbill
			H. Michael Krimbill
			Chief Executive Officer
Date: August 9, 2022		By:	/s/ Linda J. Bridges
			Linda J. Bridges
			Chief Financial Officer

52

Document

Exhibit 31.1

CERTIFICATION

I, H. Michael Krimbill, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q of NGL Energy Partners LP;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.    The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a.    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 9, 2022	/s/ H. Michael Krimbill
	H. Michael Krimbill
	Chief Executive Officer of NGL Energy Holdings LLC, the general partner of NGL Energy Partners LP

Document

Exhibit 31.2

CERTIFICATION

I, Linda J. Bridges, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q of NGL Energy Partners LP;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.    Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.    Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.    Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.    The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a.    All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.    Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 9, 2022	/s/ Linda J. Bridges
	Linda J. Bridges
	Chief Financial Officer of NGL Energy Holdings LLC, the general partner of NGL Energy Partners LP

Document

Exhibit 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350

In connection with the Quarterly Report of NGL Energy Partners LP (the “Partnership”) on Form 10-Q for the fiscal quarter ended June 30, 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, H. Michael Krimbill, Chief Executive Officer of NGL Energy Holdings LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (“Section 906”), that, to my knowledge:

1.    The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.    The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

Date: August 9, 2022	/s/ H. Michael Krimbill
	H. Michael Krimbill
	Chief Executive Officer of NGL Energy Holdings LLC, the general partner of NGL Energy Partners LP

This certification is being furnished solely pursuant to Section 906 and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.

Document

Exhibit 32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350

In connection with the Quarterly Report of NGL Energy Partners LP (the “Partnership”) on Form 10-Q for the fiscal quarter ended June 30, 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Linda J. Bridges, Chief Financial Officer of NGL Energy Holdings LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (“Section 906”), that, to my knowledge:

1.    The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.    The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

Date: August 9, 2022	/s/ Linda J. Bridges
	Linda J. Bridges
	Chief Financial Officer of NGL Energy Holdings LLC, the general partner of NGL Energy Partners LP

This certification is being furnished solely pursuant to Section 906 and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.