UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended June 30, ~~2021~~2022

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

Commission file number 1-12295

GENESIS ENERGY, L.P.

(Exact name of registrant as specified in its charter)

Delaware

76-0513049

(State or other jurisdiction of
incorporation or organization)

(I.R.S. Employer
Identification No.)

919 Milam, Suite 2100,

Houston

77002

(Address of principal executive offices)

(Zip code)

Registrant’s telephone number, including area code:

(713)

860-2500


Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
Common units	GEL	NYSE

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 ý 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 ý No ¨

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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

Accelerated filer

Non-accelerated filer

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 ý

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date. There were 122,539,221 Class A Common Units and 39,997 Class B Common Units outstanding as of ~~August 4, 2021.~~July 29, 2022.

Table of Contents

GENESIS ENERGY, L.P.

TABLE OF CONTENTS


		Page
	PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	~~Unaudited~~ Condensed Consolidated Balance Sheets as of June 3 0 , 2022 (unaudited) and December 31, 2021	3
	Unaudited Condensed Consolidated Statements of Operations	4
	Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)	5
	Unaudited Condensed Consolidated Statements of Partners’ Capital	6
	Unaudited Condensed Consolidated Statements of Cash Flows	7
	Notes to Unaudited Condensed Consolidated Financial Statements	8
	1. Organization and Basis of Presentation and Consolidation	8
	2. Recent Accounting Developments	98
	3. Revenue Recognition	9
	4. Lease Accounting	1110
	5. Inventories	1211
	6. Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	1312
	7. Equity Investees	1413
	8. Intangible Assets	1514
	9. Debt	1615
	10. ~~Partners'~~Partners ’ Capital, Mezzanine Capital and Distributions	1817
	11. Net Income (Loss ) Per Common Unit	2119
	12. Business Segment Information	2220
	13. Transactions with Related Parties	2523
	14. Supplemental Cash Flow Information	2624
	15. Derivatives	2624
	16. Fair-Value Measurements	2928
	17. Commitments and Contingencies	3029

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3230
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	54
Item 4.	Controls and Procedures	54
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	55
Item 1A.	Risk Factors	55
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	55
Item 3.	Defaults upon Senior Securities	55
Item 4.	Mine Safety Disclosures	55
Item 5.	Other Information	55
Item 6.	Exhibits	56
SIGNATURES		57

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

GENESIS ENERGY, L.P.

~~UNAUDITED~~ CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except units)


							June 30, 2022		December 31, 2021
		June 30, 2021		December 31, 2020			(unaudited)
ASSETS	ASSETS					ASSETS
CURRENT ASSETS:	CURRENT ASSETS:					CURRENT ASSETS:
Cash and cash equivalents	Cash and cash equivalents	$	24,205	$	21,282	Cash and cash equivalents	$	10,070	$	19,987
Restricted cash	Restricted cash	22,083		5,736		Restricted cash	18,446		5,005
Accounts receivable - trade, net	Accounts receivable - trade, net	433,310		392,465		Accounts receivable - trade, net	453,502		400,334
Inventories	Inventories	78,327		99,877		Inventories	91,834		77,958

Other	Other	61,796		60,809		Other	31,239		39,200
Total current assets	Total current assets	619,721		580,169		Total current assets	605,091		542,484
FIXED ASSETS, at cost	FIXED ASSETS, at cost	5,312,157		5,173,475		FIXED ASSETS, at cost	5,599,512		5,464,040
Less: Accumulated depreciation	Less: Accumulated depreciation	(1,437,510)		(1,322,141)		Less: Accumulated depreciation	(1,661,837)		(1,551,855)
Net fixed assets	Net fixed assets	3,874,647		3,851,334		Net fixed assets	3,937,675		3,912,185
MINERAL LEASEHOLDS, net of accumulated depletion	MINERAL LEASEHOLDS, net of accumulated depletion	550,959		552,575		MINERAL LEASEHOLDS, net of accumulated depletion	547,071		549,005

EQUITY INVESTEES	EQUITY INVESTEES	302,940		319,068		EQUITY INVESTEES	287,748		294,050
INTANGIBLE ASSETS, net of amortization	INTANGIBLE ASSETS, net of amortization	127,947		128,742		INTANGIBLE ASSETS, net of amortization	126,700		127,063
GOODWILL	GOODWILL	301,959		301,959		GOODWILL	301,959		301,959
RIGHT OF USE ASSETS, net	RIGHT OF USE ASSETS, net	144,013		153,925		RIGHT OF USE ASSETS, net	133,476		140,796
OTHER ASSETS, net of amortization	OTHER ASSETS, net of amortization	41,301		45,847		OTHER ASSETS, net of amortization	31,740		38,259
TOTAL ASSETS	TOTAL ASSETS	$	5,963,487	$	5,933,619	TOTAL ASSETS	$	5,971,460	$	5,905,801
LIABILITIES AND CAPITAL	LIABILITIES AND CAPITAL					LIABILITIES AND CAPITAL
CURRENT LIABILITIES:	CURRENT LIABILITIES:					CURRENT LIABILITIES:
Accounts payable - trade	Accounts payable - trade	$	301,676	$	198,433	Accounts payable - trade	$	256,086	$	264,316
Accrued liabilities	Accrued liabilities	218,327		184,978		Accrued liabilities	253,369		232,623

Total current liabilities	Total current liabilities	520,003		383,411		Total current liabilities	509,455		496,939
SENIOR SECURED CREDIT FACILITY, net		415,653		643,700
SENIOR UNSECURED NOTES, net		2,927,489		2,750,016
SENIOR SECURED CREDIT FACILITY						SENIOR SECURED CREDIT FACILITY	34,600		49,000
SENIOR UNSECURED NOTES, net of debt issuance costs and premium						SENIOR UNSECURED NOTES, net of debt issuance costs and premium	2,888,422		2,930,505
ALKALI SENIOR SECURED NOTES, net of debt issuance costs and discount						ALKALI SENIOR SECURED NOTES, net of debt issuance costs and discount	402,204		—
DEFERRED TAX LIABILITIES	DEFERRED TAX LIABILITIES	13,719		13,317		DEFERRED TAX LIABILITIES	14,897		14,297
OTHER LONG-TERM LIABILITIES	OTHER LONG-TERM LIABILITIES	422,299		393,018		OTHER LONG-TERM LIABILITIES	441,226		434,925
Total liabilities	Total liabilities	4,299,163		4,183,462		Total liabilities	4,290,804		3,925,666

MEZZANINE CAPITAL:	MEZZANINE CAPITAL:					MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at June 30, 2021 and December 31, 2020		790,115		790,115
Redeemable noncontrolling interests, 201,705 and 141,249 preferred units issued and outstanding at June 30, 2021 and December 31, 2020, respectively		204,647		141,194
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at June 30, 2022 and December 31, 2021						Class A Convertible Preferred Units, 25,336,778 issued and outstanding at June 30, 2022 and December 31, 2021	790,115		790,115
Redeemable noncontrolling interests, 0 units issued and outstanding at June 30, 2022 and 246,394 preferred units issued and outstanding December 31, 2021						Redeemable noncontrolling interests, 0 units issued and outstanding at June 30, 2022 and 246,394 preferred units issued and outstanding December 31, 2021	—		259,568

PARTNERS’ CAPITAL:	PARTNERS’ CAPITAL:					PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at June 30, 2021 and December 31, 2020		679,278		829,326
Common unitholders, 122,579,218 units issued and outstanding at June 30, 2022 and December 31, 2021						Common unitholders, 122,579,218 units issued and outstanding at June 30, 2022 and December 31, 2021	596,059		641,313
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(9,122)		(9,365)		Accumulated other comprehensive loss	(5,364)		(5,607)
Noncontrolling interests	Noncontrolling interests	(594)		(1,113)		Noncontrolling interests	299,846		294,746
Total partners' capital		669,562		818,848
Total partners’ capital						Total partners’ capital	890,541		930,452
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$	5,963,487	$	5,933,619	TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$	5,971,460	$	5,905,801

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands)


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
REVENUES:	REVENUES:									REVENUES:
Offshore pipeline transportation	Offshore pipeline transportation	$	73,221	$	64,964	$	137,605	$	143,393	Offshore pipeline transportation	$	82,085	$	73,221	$	150,153	$	137,605
Sodium minerals and sulfur services	Sodium minerals and sulfur services	237,087		192,624		464,374		436,014		Sodium minerals and sulfur services	318,608		237,087		604,282		464,374
Marine transportation	Marine transportation	47,626		56,720		87,957		119,066		Marine transportation	76,320		47,626		132,094		87,957
Onshore facilities and transportation	Onshore facilities and transportation	145,921		74,159		335,138		229,917		Onshore facilities and transportation	244,712		145,921		467,143		335,138
Total revenues	Total revenues	503,855		388,467		1,025,074		928,390		Total revenues	721,725		503,855		1,353,672		1,025,074
COSTS AND EXPENSES:	COSTS AND EXPENSES:									COSTS AND EXPENSES:
Onshore facilities and transportation product costs	Onshore facilities and transportation product costs	124,684		43,447		285,435		155,399		Onshore facilities and transportation product costs	217,703		124,684		417,305		285,435
Onshore facilities and transportation operating costs	Onshore facilities and transportation operating costs	15,833		18,238		32,095		36,486		Onshore facilities and transportation operating costs	16,902		15,833		32,579		32,095
Marine transportation operating costs	Marine transportation operating costs	39,118		38,561		72,204		81,498		Marine transportation operating costs	58,924		39,118		102,652		72,204
Sodium minerals and sulfur services operating costs	Sodium minerals and sulfur services operating costs	196,971		167,010		381,402		372,243		Sodium minerals and sulfur services operating costs	250,914		196,971		464,539		381,402
Offshore pipeline transportation operating costs	Offshore pipeline transportation operating costs	21,264		16,403		41,980		35,064		Offshore pipeline transportation operating costs	26,359		21,264		49,375		41,980
General and administrative	General and administrative	12,907		25,413		24,573		34,786		General and administrative	20,665		12,907		35,787		24,573
Depreciation, depletion and amortization	Depreciation, depletion and amortization	67,541		80,120		133,827		154,477		Depreciation, depletion and amortization	73,673		67,541		143,179		133,827
Impairment expense		0		277,495		0		277,495
Gain on sale of asset										Gain on sale of asset	(40,000)		—		(40,000)		—

Total costs and expenses	Total costs and expenses	478,318		666,687		971,516		1,147,448		Total costs and expenses	625,140		478,318		1,205,416		971,516
OPERATING INCOME (LOSS)		25,537		(278,220)		53,558		(219,058)
OPERATING INCOME										OPERATING INCOME	96,585		25,537		148,256		53,558
Equity in earnings of equity investees	Equity in earnings of equity investees	14,222		12,618		34,882		26,777		Equity in earnings of equity investees	14,572		14,222		27,016		34,882
Interest expense	Interest expense	(59,169)		(51,618)		(116,998)		(106,583)		Interest expense	(55,959)		(59,169)		(111,063)		(116,998)
Other income (expense)	Other income (expense)	(15,845)		(4,550)		(35,910)		5,708		Other income (expense)	14,888		(15,845)		10,630		(35,910)
Loss from operations before income taxes		(35,255)		(321,770)		(64,468)		(293,156)
Income (loss) from operations before income taxes										Income (loss) from operations before income taxes	70,086		(35,255)		74,839		(64,468)
Income tax expense	Income tax expense	(525)		(795)		(747)		(430)		Income tax expense	(571)		(525)		(875)		(747)

NET LOSS		(35,780)		(322,565)		(65,215)		(293,586)
Net loss (income) attributable to noncontrolling interests		(136)		10		(134)		26
NET INCOME (LOSS)										NET INCOME (LOSS)	69,515		(35,780)		73,964		(65,215)
Net income attributable to noncontrolling interests										Net income attributable to noncontrolling interests	(11,548)		(136)		(13,424)		(134)
Net income attributable to redeemable noncontrolling interests	Net income attributable to redeemable noncontrolling interests	(5,766)		(4,159)		(10,557)		(8,245)		Net income attributable to redeemable noncontrolling interests	(22,620)		(5,766)		(30,443)		(10,557)
NET LOSS ATTRIBUTABLE TO GENESIS ENERGY, L.P.		$	(41,682)	$	(326,714)	$	(75,906)	$	(301,805)
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.										NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.	$	35,347	$	(41,682)	$	30,097	$	(75,906)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(37,368)		(37,368)		Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(37,368)		(37,368)
NET LOSS AVAILABLE TO COMMON UNITHOLDERS		$	(60,366)	$	(345,398)	$	(113,274)	$	(339,173)
NET LOSS PER COMMON UNIT (Note 11):
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON UNITHOLDERS										NET INCOME (LOSS) ATTRIBUTABLE TO COMMON UNITHOLDERS	$	16,663	$	(60,366)	$	(7,271)	$	(113,274)
NET INCOME (LOSS) PER COMMON UNIT (Note 11):										NET INCOME (LOSS) PER COMMON UNIT (Note 11):

Basic and Diluted	Basic and Diluted	$	(0.49)	$	(2.82)	$	(0.92)	$	(2.77)	Basic and Diluted	$	0.14	$	(0.49)	$	(0.06)	$	(0.92)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:	WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:									WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted	Basic and Diluted	122,579		122,579		122,579		122,579		Basic and Diluted	122,579		122,579		122,579		122,579

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Net loss $ (35,780) $ (322,565) $ (65,215) $ (293,586)
Other comprehensive income:
Amortization of prior service cost 121 243 243 243
Total Comprehensive loss (35,659) (322,322) (64,972) (293,343)
Comprehensive loss (income) attributable to noncontrolling interests (136) 10 (134) 26
Comprehensive income attributable to redeemable noncontrolling interests (5,766) (4,159) (10,557) (8,245)
Comprehensive loss attributable to Genesis Energy, L.P. $ (41,561) $ (326,471) $ (75,663) $ (301,562)


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Net income (loss)	$	69,515	$	(35,780)	$	73,964	$	(65,215)
Other comprehensive income:
Amortization of prior year service cost	121		121		243		243
Total Comprehensive income (loss)	69,636		(35,659)		74,207		(64,972)
Comprehensive income attributable to noncontrolling interests	(11,548)		(136)		(13,424)		(134)
Comprehensive income attributable to redeemable noncontrolling interests	(22,620)		(5,766)		(30,443)		(10,557)
Comprehensive income (loss) attributable to Genesis Energy, L.P.	$	35,468	$	(41,561)	$	30,340	$	(75,663)

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(In thousands)

Number of Common Units Partners’ Capital Noncontrolling Interest Accumulated Other Comprehensive Loss Total
Partners' capital, March 31, 2021 122,579 $ 758,031 $ (879) $ (9,243) $ 747,909
Net income (loss) — (41,682) 136 — (41,546)
Cash distributions to partners — (18,387) — — (18,387)
Cash contributions from noncontrolling interests — — 149 — 149
Other comprehensive income — — — 121 121
Distributions to Class A Convertible Preferred unitholders — (18,684) — — (18,684)
Partners' capital, June 30, 2021 122,579 $ 679,278 $ (594) $ (9,122) $ 669,562
Number of Common Units Partners’ Capital Noncontrolling Interest Accumulated Other Comprehensive Loss Total
Partners' capital, March 31, 2020 122,579 $ 1,382,126 $ (2,357) $ (8,431) $ 1,371,338
Net loss — (326,714) (10) — (326,724)
Cash distributions to partners — (18,386) — — (18,386)
Cash contributions from noncontrolling interests — — 467 — 467
Other comprehensive income — — — 243 243
Distributions to Class A Convertible Preferred unitholders — (18,684) — — (18,684)
Partners' capital, June 30, 2020 122,579 $ 1,018,342 $ (1,900) $ (8,188) $ 1,008,254


	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, March 31, 2022	122,579	$	597,783	$	293,451	$	(5,485)	$	885,749
Net income	—	35,347		11,548		—		46,895
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash distributions to noncontrolling interests	—	—		(13,130)		—		(13,130)
Cash contributions from noncontrolling interests	—	—		7,977		—		7,977
Other comprehensive income	—	—		—		121		121
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)


Partners’ capital, June 30, 2022	122,579	$	596,059	$	299,846	$	(5,364)	$	890,541

	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, March 31, 2021	122,579	$	758,031	$	(879)	$	(9,243)	$	747,909
Net income (loss)	—	(41,682)		136		—		(41,546)
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash contributions from noncontrolling interests	—	—		149		—		149
Other comprehensive income	—	—		—		121		121
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)
Partners’ capital, June 30, 2021	122,579	$	679,278	$	(594)	$	(9,122)	$	669,562


	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2021	122,579	$	641,313	$	294,746	$	(5,607)	$	930,452
Net income	—	30,097		13,424		—		43,521
Cash distributions to partners	—	(36,774)		—		—		(36,774)
Adjustment to valuation of noncontrolling interest in subsidiary	—	(1,209)		1,209		—		—
Cash distributions to noncontrolling interests	—	—		(18,332)		—		(18,332)
Cash contributions from noncontrolling interests	—	—		8,799		—		8,799
Other comprehensive income	—	—		—		243		243
Distributions to Class A Convertible Preferred unitholders	—	(37,368)		—		—		(37,368)


Partners’ capital, June 30, 2022	122,579	$	596,059	$	299,846	$	(5,364)	$	890,541
	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2020	122,579	$	829,326	$	(1,113)	$	(9,365)	$	818,848
Net income (loss)	—	(75,906)		134		—		(75,772)
Cash distributions to partners	—	(36,774)		—		—		(36,774)
Cash contributions from noncontrolling interests	—	—		385		—		385
Other comprehensive income	—	—		—		243		243
Distributions to Class A Convertible Preferred unitholders	—	(37,368)		—		—		(37,368)
Partners’ capital, June 30, 2021	122,579	$	679,278	$	(594)	$	(9,122)	$	669,562

Number of
Common Units Partners’ Capital Noncontrolling Interest Accumulated Other Comprehensive Loss Total
Partners’ capital, December 31, 2020 122,579 $ 829,326 $ (1,113) $ (9,365) $ 818,848
Net income (loss) — (75,906) 134 — (75,772)
Cash distributions to partners — (36,774) — — (36,774)
Cash contributions from noncontrolling interests — — 385 — 385
Other comprehensive income — — — 243 243
Distributions to Class A Convertible Preferred unitholders — (37,368) — — (37,368)
Partners' capital, June 30, 2021 122,579 $ 679,278 $ (594) $ (9,122) $ 669,562
Number of
Common Units Partners’ Capital Noncontrolling Interest Accumulated Other Comprehensive Loss Total
Partners’ capital, December 31, 2019 122,579 $ 1,443,320 $ (3,718) $ (8,431) $ 1,431,171
Net loss — (301,805) (26) — (301,831)
Cash distributions to partners — (85,805) — — (85,805)
Cash contributions from noncontrolling interests — — 1,844 — 1,844
Other comprehensive income — — — 243 243
Distributions to Class A Convertible Preferred unitholders — (37,368) — — (37,368)
Partners' capital, June 30, 2020 122,579 $ 1,018,342 $ (1,900) $ (8,188) $ 1,008,254

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)


		Six Months Ended June 30,					Six Months Ended June 30,
		2021		2020			2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES:	CASH FLOWS FROM OPERATING ACTIVITIES:					CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss		$	(65,215)	$	(293,586)
Adjustments to reconcile net loss to net cash provided by operating activities -
Net income (loss)						Net income (loss)	$	73,964	$	(65,215)
Adjustments to reconcile net income (loss) to net cash provided by operating activities -						Adjustments to reconcile net income (loss) to net cash provided by operating activities -
Depreciation, depletion and amortization	Depreciation, depletion and amortization	133,827		154,477		Depreciation, depletion and amortization	143,179		133,827

Impairment expense		0		277,495
Gain on sale of asset						Gain on sale of asset	(40,000)		—

Amortization and write-off of debt issuance costs, premium and discount	Amortization and write-off of debt issuance costs, premium and discount	6,965		14,971		Amortization and write-off of debt issuance costs, premium and discount	4,652		6,965
Amortization of non-cash costs on previously owned direct financing leases		0		(5,802)
Payments received under previously owned direct financing leases (Note 4)		35,000		10,334

Payments received under previously owned direct financing leases						Payments received under previously owned direct financing leases	—		35,000
Equity in earnings of investments in equity investees	Equity in earnings of investments in equity investees	(34,882)		(26,777)		Equity in earnings of investments in equity investees	(27,016)		(34,882)
Cash distributions of earnings of equity investees	Cash distributions of earnings of equity investees	34,325		25,923		Cash distributions of earnings of equity investees	27,378		34,325
Non-cash effect of long-term incentive compensation plans	Non-cash effect of long-term incentive compensation plans	2,884		(3,647)		Non-cash effect of long-term incentive compensation plans	6,644		2,884
Deferred and other tax liabilities	Deferred and other tax liabilities	402		130		Deferred and other tax liabilities	600		402
Unrealized losses (gains) on derivative transactions	Unrealized losses (gains) on derivative transactions	32,377		(9,811)		Unrealized losses (gains) on derivative transactions	(10,284)		32,377
Cancellation of debt income	Cancellation of debt income	0		(19,725)		Cancellation of debt income	(4,737)		—
Other, net	Other, net	11,229		8,662		Other, net	10,137		11,229
Net changes in components of operating assets and liabilities (Note 14)	Net changes in components of operating assets and liabilities (Note 14)	31,272		19,518		Net changes in components of operating assets and liabilities (Note 14)	(26,230)		31,272
Net cash provided by operating activities	Net cash provided by operating activities	188,184		152,162		Net cash provided by operating activities	158,287		188,184
CASH FLOWS FROM INVESTING ACTIVITIES:	CASH FLOWS FROM INVESTING ACTIVITIES:					CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	Payments to acquire fixed and intangible assets	(111,412)		(69,438)		Payments to acquire fixed and intangible assets	(181,441)		(111,412)
Cash distributions received from equity investees - return of investment	Cash distributions received from equity investees - return of investment	17,015		13,036		Cash distributions received from equity investees - return of investment	10,372		17,015

Investments in equity investees						Investments in equity investees	(2,976)		—

Proceeds from asset sales	Proceeds from asset sales	32		304		Proceeds from asset sales	40,131		32

Net cash used in investing activities	Net cash used in investing activities	(94,365)		(56,098)		Net cash used in investing activities	(133,914)		(94,365)
CASH FLOWS FROM FINANCING ACTIVITIES:	CASH FLOWS FROM FINANCING ACTIVITIES:					CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	Borrowings on senior secured credit facility	366,600		684,500		Borrowings on senior secured credit facility	403,000		366,600
Repayments on senior secured credit facility	Repayments on senior secured credit facility	(592,100)		(590,800)		Repayments on senior secured credit facility	(417,400)		(592,100)
Net proceeds from issuance of Alkali senior secured notes (Note 9)						Net proceeds from issuance of Alkali senior secured notes (Note 9)	408,000		—
Redemption of preferred units (Note 10)						Redemption of preferred units (Note 10)	(288,629)		—
Proceeds from issuance of senior unsecured notes (Note 9)	Proceeds from issuance of senior unsecured notes (Note 9)	259,375		750,000		Proceeds from issuance of senior unsecured notes (Note 9)	—		259,375
Net proceeds from issuance of preferred units (Note 10)	Net proceeds from issuance of preferred units (Note 10)	53,018		0		Net proceeds from issuance of preferred units (Note 10)	—		53,018
Repayment of senior unsecured notes (Note 9)	Repayment of senior unsecured notes (Note 9)	(80,859)		(820,713)		Repayment of senior unsecured notes (Note 9)	(40,837)		(80,859)
Debt issuance costs	Debt issuance costs	(11,365)		(13,297)		Debt issuance costs	(5,770)		(11,365)

Contributions from noncontrolling interests	Contributions from noncontrolling interests	385		1,844		Contributions from noncontrolling interests	8,799		385
Distributions to noncontrolling interests						Distributions to noncontrolling interests	(18,332)		—
Distributions to common unitholders	Distributions to common unitholders	(36,774)		(85,805)		Distributions to common unitholders	(36,774)		(36,774)
Distributions to preferred unitholders		(37,368)		(37,368)
Distributions to Class A Convertible Preferred unitholders						Distributions to Class A Convertible Preferred unitholders	(37,368)		(37,368)
Other, net	Other, net	4,539		4,671		Other, net	4,462		4,539
Net cash used in financing activities	Net cash used in financing activities	(74,549)		(106,968)		Net cash used in financing activities	(20,849)		(74,549)
Net increase (decrease) in cash, restricted cash, and cash equivalents		19,270		(10,904)
Cash, restricted cash and cash equivalents at beginning of period		27,018		56,405
Cash, restricted cash and cash equivalents at end of period		$	46,288	$	45,501
Net increase in cash, cash equivalents and restricted cash						Net increase in cash, cash equivalents and restricted cash	3,524		19,270
Cash, cash equivalents and restricted cash at beginning of period						Cash, cash equivalents and restricted cash at beginning of period	24,992		27,018
Cash, cash equivalents and restricted cash at end of period						Cash, cash equivalents and restricted cash at end of period	$	28,516	$	46,288

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Organization and Basis of Presentation and Consolidation

Organization

We are a growth-oriented master limited partnership ~~formed~~founded in Delaware in 1996 and focused on the midstream segment of the crude oil and natural gas industry as well as the production of natural soda ash. Our operations are primarily located ~~primarily~~ in the Gulf Coast region of the United States, Wyoming and in the Gulf of Mexico. We provide an integrated suite of services to refiners, crude oil and natural gas producers and industrial and commercial enterprises and have a diverse portfolio of assets, including pipelines, offshore hub and junction platforms, our trona and trona-based exploring, mining, processing, producing, marketing and selling business based in Wyoming (our ~~"Alkali Business"~~“Alkali Business”), refinery-related plants, storage tanks and terminals, railcars, rail unloading facilities, barges and other vessels and trucks. We are owned 100% by our limited partners. Genesis Energy, LLC, our general partner, is a wholly-owned subsidiary. Our general partner has sole responsibility for conducting our business and managing our operations. We conduct our operations and own our operating assets through our subsidiaries and joint ventures.

We currently manage our businesses through the following 4 divisions that constitute our reportable segments:

•Offshore pipeline transportation, ~~and~~which includes processing of crude oil and natural gas in the Gulf of Mexico;

•Sodium minerals and sulfur services involving trona and trona-based exploring, mining, processing, ~~producing,~~ marketing and selling activities, as well as ~~the~~soda ash production and processing of high sulfur (or ~~"sour"~~“sour”) gas streams for refineries to remove the sulfur and ~~the~~ selling of the related by-product, sodium hydrosulfide (or ~~"NaHS",~~“NaHS,” commonly pronounced ~~"nash"~~“nash”);

•Onshore facilities and transportation, which include ~~the terminalling,~~terminaling, blending, storing, marketing and transporting of crude oil and petroleum products (primarily fuel oil, asphalt and other heavy refined products); and

•Marine transportation to provide waterborne transportation of petroleum products (primarily fuel oil, asphalt and other heavy refined products) and crude oil throughout North ~~America.~~America

Basis of Presentation and Consolidation

The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including our general partner, Genesis Energy, LLC.

Our results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the fiscal year. The Unaudited Condensed Consolidated Financial Statements included herein have been prepared by us without audit pursuant to the rules and regulations of the Securities and Exchange Commission (the ~~"SEC"~~“SEC”). Accordingly, they reflect all adjustments (which consist solely of normal recurring adjustments) that are, in the opinion of management, necessary for a fair presentation of the financial results for interim periods. Certain information and notes normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles ~~("GAAP"~~(“GAAP”) have been condensed or omitted pursuant to such rules and regulations. However, we believe that the disclosures are adequate to make the information presented not misleading when read in conjunction with the information contained in the periodic reports we file with the SEC pursuant to the Securities Exchange Act of 1934, including the Consolidated Financial Statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 (our ~~"Annual Report"~~“Annual Report”).

Except per unit amounts, or as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars.

~~Covid-19~~

2. Recent Accounting Developments

Recent and ~~Market Update~~Proposed Accounting Pronouncements

In March 2020, the ~~World Health Organization categorized Covid-19 as a pandemic,~~FASB issued ASU 2020-04, Reference Rate Reform (Topic 848), which provides expedients and exceptions for accounting treatment of contracts which are affected by the ~~President~~anticipated discontinuation of the ~~United States declared~~London InterBank Offered Rate (“LIBOR”) and other rates resulting from rate reform that are entered into on or before December 31, 2022. Contract terms that are modified due to the ~~Covid-19 outbreak~~replacement of a ~~national emergency. Our operations,~~reference rate are not required to be remeasured or reassessed under relevant accounting standards. On May 17, 2022, we entered into our Second Amendment and Consent to the credit agreement (defined in Note 9), which ~~fall within~~among other things, replaced our existing LIBOR rate based borrowings with the ~~energy, mining~~Term SOFR rate, which is based on the Secured Overnight Financing Rate (“SOFR”) borrowings. The impact to our senior secured credit facility and ~~transportation sectors, are considered critical and essential by the Department of Homeland Security's CISA and we have continued~~related interest expense upon transition to ~~operate our assets during this pandemic.~~

WeSOFR did not have a ~~designated internal management team~~material impact on our Unaudited Condensed Consolidated Financial Statements. Refer to provide resources, updates, and support to our entire workforce during this pandemic, while maintaining a focus to ensure safety and well-being of our employees, the families of our employees, and the communities in which our businesses operate. We will continue to operate in the best interests of our employees, stakeholders, customers, partners, and suppliers and make any necessary changes as required by federal, state, or local authorities as we continue to actively monitor the situation.Note 9 for more details.

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GENESIS ENERGY, L.P.

Beginning in March 2020, Covid-19 caused commodity prices to decline due to, among other things, reduced industrial activity and travel demand. Additionally, actions taken by OPEC and other oil exporting nationsNOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

in that timeframe caused additional significant declines and volatility in the price of oil and gas. We continue to monitor the market environment and will evaluate whether any triggering events would indicate possible impairments of long-lived assets, intangible assets and goodwill. Management’s estimates are based on numerous assumptions about future operations and market conditions, which we believe to be reasonable but are inherently uncertain. The uncertainties underlying our assumptions and estimates could differ significantly from actual results, including with respect to the duration and severity of the Covid-19 pandemic. In the current volatile economic environment and to the extent conditions deteriorate, we may identify triggering events that may require future evaluations of the recoverability of the carrying value of our long-lived assets, intangible assets and goodwill, which could result in impairment charges that could be material to our results of operations.

~~2. Recent Accounting Developments~~

~~Recently Adopted~~

During the first quarter of 2020, the SEC amended the financial disclosure requirements for guarantors and issuers of guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X to go in effect January 4, 2021. The amendment simplifies the disclosure requirements and permits the amended disclosures to be provided outside the footnotes in audited annual or unaudited interim consolidated financial statements in all filings. As permitted by the amendment, we have early adopted the amendment and included the required summarized financial information in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

3. Revenue Recognition

Revenue from Contracts with Customers

The following tables reflect the disaggregation of our revenues by major category for the three months ended June 30, ~~2021~~2022 and ~~2020,~~2021, respectively:


		Three Months Ended June 30, 2021											Three Months Ended June 30, 2022
		Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated			Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	Fee-based revenues	$	73,221	$	0	$	47,626	$	18,176	$	139,023	Fee-based revenues	$	82,085	$	—	$	76,320	$	20,471	$	178,876
Product Sales	Product Sales	0		212,434		0		127,745		340,179		Product Sales	—		287,940		—		224,241		512,181
Refinery Services	Refinery Services	0		24,653		0		0		24,653		Refinery Services	—		30,668		—		—		30,668
		$	73,221	$	237,087	$	47,626	$	145,921	$	503,855		$	82,085	$	318,608	$	76,320	$	244,712	$	721,725

Three Months Ended
June 30, 2020
Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated
Fee-based revenues $ 64,964 $ 0 $ 56,720 $ 21,845 $ 143,529
Product Sales 0 172,410 0 52,314 224,724
Refinery Services 0 20,214 0 0 20,214
$ 64,964 $ 192,624 $ 56,720 $ 74,159 $ 388,467

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~


	Three Months Ended June 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities & Transportation		Consolidated
Fee-based revenues	$	73,221	$	—	$	47,626	$	18,176	$	139,023
Product Sales	—		212,434		—		127,745		340,179
Refinery Services	—		24,653		—		—		24,653
	$	73,221	$	237,087	$	47,626	$	145,921	$	503,855

The following tables reflect the disaggregation of our revenues by major category for the six months ended June 30, ~~2021~~2022 and ~~2020,~~2021, respectively:


		Six Months Ended June 30, 2021											Six Months Ended June 30, 2022
		Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated			Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	Fee-based revenues	$	137,605	$	0	$	87,957	$	42,570	$	268,132	Fee-based revenues	$	150,153	$	—	$	132,094	$	34,103	$	316,350
Product Sales	Product Sales	0		417,212		0		292,568		709,780		Product Sales	—		546,715		—		433,040		979,755
Refinery Services	Refinery Services	0		47,162		0		0		47,162		Refinery Services	—		57,567		—		—		57,567
		$	137,605	$	464,374	$	87,957	$	335,138	$	1,025,074		$	150,153	$	604,282	$	132,094	$	467,143	$	1,353,672


		Six Months Ended June 30, 2020											Six Months Ended June 30, 2021
		Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities & Transportation		Consolidated			Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	Fee-based revenues	$	143,393	$	0	$	119,066	$	62,835	$	325,294	Fee-based revenues	$	137,605	$	—	$	87,957	$	42,570	$	268,132
Product Sales	Product Sales	0		387,776		0		167,082		554,858		Product Sales	—		417,212		—		292,568		709,780
Refinery Services	Refinery Services	0		48,238		0		0		48,238		Refinery Services	—		47,162		—		—		47,162
		$	143,393	$	436,014	$	119,066	$	229,917	$	928,390		$	137,605	$	464,374	$	87,957	$	335,138	$	1,025,074

The Company recognizes revenue upon the satisfaction of its performance obligations under its contracts. The timing of revenue recognition varies for our different revenue streams. In general, the timing includes recognition of revenue over time as services are being performed as well as recognition of revenue at a point in time for delivery of products.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Contract Assets and Liabilities

The table below depicts our contract asset and liability balances at December 31, ~~2020~~2021 and June 30, ~~2021:~~2022:

Contract Assets Contract Liabilities
Current Assets- Other Other Assets Accrued Liabilities Other Long-Term Liabilities
Balance at December 31, 2020 $ 36,500 $ 12,065 $ 2,988 $ 19,834
Balance at June 30, 2021 30,813 0 2,669 18,576


	Contract Assets		Contract Liabilities
	Current Assets- Other			Accrued Liabilities		Other Long-Term Liabilities
Balance at December 31, 2021	$	13,563		$	2,619	$	19,028
Balance at June 30, 2022	751			11,898		26,369

Transaction Price Allocations to Remaining Performance Obligations

We are required to disclose the amount of our transaction prices that are allocated to unsatisfied performance obligations as of June 30, ~~2021.~~2022. We are ~~exempted~~exempt from disclosing performance obligations with a duration of one year or less, revenue recognized related to performance obligations where the consideration corresponds directly with the value provided to customers and contracts with variable consideration that is allocated wholly to an unsatisfied performance obligation or promise to transfer a good or service that is part of a series in accordance with ASC 606.

The majority of our contracts qualify for one of these expedients or exemptions. For the remaining contract types that involve revenue recognition over a long-term period with long-term fixed consideration (adjusted for indexing as required), we determined our allocations of transaction price that relate to unsatisfied performance obligations. For our tiered pricing offshore transportation contracts, we provide firm capacity for both fixed and variable consideration over a long term period. Therefore, we have allocated the remaining contract value to future periods.

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

The following chart depicts how we expect to recognize revenues for future periods related to these contracts:

Offshore Pipeline Transportation Onshore Facilities and Transportation
Remainder of 2021 $ 31,048 $ 9,604
2022 75,623 4,698
2023 63,982 0
2024 56,326 0
2025 60,311 0
Thereafter 97,761 0
Total $ 385,051 $ 14,302


	Offshore Pipeline Transportation		Onshore Facilities and Transportation
Remainder of 2022	$	38,085	$	3,600
2023	66,418		7,200
2024	59,637		1,800
2025	63,279		—
2026	45,131		—
Thereafter	57,612		—
Total	$	330,162	$	12,600

4. Lease Accounting

Lessee Arrangements

We lease a variety of transportation equipment ~~(including trucks, trailers, and~~(primarily railcars), terminals, land and facilities, and office space and equipment. Lease terms vary and can range from short term (under 12 months) to long term (greater than 12 months). A majority of our leases contain options to extend the life of the lease at our sole discretion. We considered these options when determining the lease terms used to derive our right of use assets and associated lease liabilities. Leases with a term of less than 12 months are not recorded on our Unaudited Condensed Consolidated Balance ~~Sheets. Lease expenses are recognized~~Sheets and we recognize lease expense for these leases on a ~~straight line~~straight-line basis over the lease term.

Our ~~Right~~“Right of Use Assets, ~~net~~net” balance includes our unamortized initial direct costs associated with certain of our transportation equipment leases. Additionally, it includes our unamortized prepaid rents, our deferred rents, and our previously classified intangible asset associated with a favorable lease. Our lease liability includes our cease-use provision for railcars no longer in use. Our short-term and long-term lease liabilities are recorded within ~~"Accrued liabilities"~~“Accrued liabilities” and ~~"Other~~“Other long-term liabilities,"” respectively, on our Unaudited Condensed Consolidated Balance Sheets.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Lessor Arrangements

We have the following contracts in which we act as a lessor. We also, from time to time, sublease certain of our transportation and facilities equipment to third parties.

Operating Leases

During the three and six months ended June 30, ~~2021~~2022 and ~~2020,~~2021, we acted as a lessor in a revenue ~~contracts~~contract associated with the M/T American Phoenix, which is included in our marine transportation segment. ~~During the three and six months ended June 30, 2020, we acted as a lessor in our Free State pipeline system, which was included in our onshore facilities and transportation segment.~~ Our lease revenues for ~~these arrangements~~this arrangement (inclusive of fixed and variable consideration) ~~are reflected in~~were $4.6 million and $3.8 million for the ~~table below:~~

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
M/T American Phoenix $ 3,819 $ 6,734 $ 7,239 $ 13,377
Free State Pipeline (1)
0 1,499 0 3,422

~~(1) We sold the Free State pipeline to a subsidiary of Denbury, Inc. ("Denbury") on October~~three months ended June 30, ~~2020.~~

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~Direct Finance Lease~~

We formerly held a direct finance lease of the Northeast Jackson Dome ("NEJD") Pipeline. Under the terms of the finance lease, we were paid a quarterly payment, which commenced in August 3, 2008. During the third quarter of 2020, our customer, Denbury, defaulted under the agreement. On October 30, 2020 we executed an agreement with our customer to accelerate the remaining principal payments on the previously owned NEJD direct financing lease, payable in 4 equal installments. During2022 and 2021, respectively, and $8.7 million and $7.2 million for the six months ended June 30, 2022 and 2021, we collected $35.0 million and we have an outstanding receivable (included within "Accounts receivable- trade, net" on the Unaudited Condensed Consolidated Balance Sheet) of $35.0 million as of June 30, 2021 from Denbury for the remaining payments due in 2021 per the agreement. Additionally as part of this transaction, we transferred the ownership of all of our CO2 assets to Denbury, including the Free State pipeline system as noted previously.

respectively.

5. Inventories

The major components of inventories were as follows:


		June 30, 2021		December 31, 2020			June 30, 2022		December 31, 2021
Petroleum products	Petroleum products	$	1,308	$	5,840	Petroleum products	$	—	$	998
Crude oil	Crude oil	23,597		37,661		Crude oil	20,767		11,834
Caustic soda	Caustic soda	4,459		5,167		Caustic soda	10,031		5,690
NaHS	NaHS	10,701		9,101		NaHS	20,232		17,040
Raw materials - Alkali operations	Raw materials - Alkali operations	7,230		7,120		Raw materials - Alkali operations	6,948		7,599
Work-in-process - Alkali operations	Work-in-process - Alkali operations	4,455		9,355		Work-in-process - Alkali operations	7,010		7,496
Finished goods, net - Alkali operations	Finished goods, net - Alkali operations	13,279		13,002		Finished goods, net - Alkali operations	12,633		13,681
Materials and supplies, net - Alkali operations	Materials and supplies, net - Alkali operations	13,298		12,631		Materials and supplies, net - Alkali operations	14,213		13,620

Total	Total	$	78,327	$	99,877	Total	$	91,834	$	77,958

Inventories are valued at the lower of cost or net realizable value. ~~The~~There was 0 adjustment to the net realizable value of inventories during the period ended June 30, 2022. As of December 31, 2021, the net realizable value of inventories were ~~recorded~~ below cost by ~~$0.5~~$2.0 million, ~~and $5.0 million as~~which triggered a reduction of ~~June 30, 2021 and December 31, 2020, respectively, therefore we reduced~~ the value of ~~our~~ inventory in our ~~Unaudited~~ Consolidated Financial Statements by ~~these amounts.~~this amount.

Materials and supplies include chemicals, maintenance supplies and spare parts which will be consumed in the mining of trona ore and production of soda ash processes.

1211

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

6. Fixed Assets, Mineral Leaseholds and Asset Retirement Obligations

Fixed Assets

Fixed assets ~~net~~ consisted of the following:

June 30, 2021 December 31, 2020
Crude oil pipelines and natural gas pipelines and related assets $ 2,821,996 $ 2,811,030
Alkali facilities, machinery, and equipment 641,619 622,598
Onshore facilities, machinery, and equipment 268,689 267,810
Transportation equipment 21,348 19,470
Marine vessels 1,011,171 998,553
Land, buildings and improvements 221,146 219,382
Office equipment, furniture and fixtures 22,185 22,001
Construction in progress 260,742 170,740
Other 43,261 41,891
Fixed assets, at cost 5,312,157 5,173,475
Less: Accumulated depreciation (1,437,510) (1,322,141)
Net fixed assets $ 3,874,647 $ 3,851,334


	June 30, 2022		December 31, 2021
Crude oil and natural gas pipelines and related assets	$	2,839,496	$	2,839,443
Alkali facilities, machinery and equipment	684,289		670,880
Onshore facilities, machinery and equipment	269,139		269,245
Transportation equipment	21,216		21,106
Marine vessels	1,016,892		1,018,284
Land, buildings and improvements	228,725		227,540
Office equipment, furniture and fixtures	26,992		23,965
Construction in progress	471,595		350,137
Other	41,168		43,440
Fixed assets, at cost	5,599,512		5,464,040
Less: Accumulated depreciation	(1,661,837)		(1,551,855)
Net fixed assets	$	3,937,675	$	3,912,185

Mineral Leaseholds

Our Mineral Leaseholds, relating to our Alkali Business, consist of the following:


		June 30, 2021		December 31, 2020			June 30, 2022		December 31, 2021
Mineral leaseholds	Mineral leaseholds	$	566,019	$	566,019	Mineral leaseholds	$	566,019	$	566,019
Less: Accumulated depletion	Less: Accumulated depletion	(15,060)		(13,444)		Less: Accumulated depletion	(18,948)		(17,014)
Mineral leaseholds, net of accumulated depletion	Mineral leaseholds, net of accumulated depletion	$	550,959	$	552,575	Mineral leaseholds, net of accumulated depletion	$	547,071	$	549,005

Our depreciation and depletion expense for the periods presented was as follows:

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Depreciation expense $ 64,148 $ 75,089 $ 126,850 $ 144,331
Depletion expense 704 841 1,616 1,804

During the second quarter of 2020, due to the challenging economic environment from the decline in commodity prices (including the collapse in the differential of Western Canadian Select to the Gulf Coast) and Covid-19, crude-by-rail transportation became uneconomic for producers and the demand and outlook for our rail logistics assets declined. As a result, we recognized impairment expense of $277.5 million associated with the rail logistics assets in our onshore facilities and transportation segment, including $272.7 million of net fixed assets and $4.8 million of right of use assets, net on the Unaudited Condensed Consolidated Balance Sheet. The fair value was calculated utilizing the income approach and assumptions were primarily based on level 3 inputs of the fair value hierarchy.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Depreciation expense	$	70,033	$	64,148	$	135,783	$	126,850
Depletion expense	914		704		1,934		1,616

Asset Retirement Obligations

We record asset retirement obligations ~~("AROs"~~(“AROs”) in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations.

The following table presents information regarding our AROs since December 31, ~~2020:~~2021:


ARO liability balance, December 31, 2021	$	220,906
Accretion expense	6,871
Changes in estimate	2,383


Settlements	(9,798)

ARO liability balance, June 30, 2022	$	220,362

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


~~ARO liability balance, December 31, 2020~~	$	~~176,852~~
~~Accretion expense~~	~~5,177~~
~~Changes in estimate~~	97


~~Settlements~~	~~(2,824)~~

~~ARO liability balance, June 30, 2021~~	$	~~179,302~~

~~Of the ARO balances disclosed above, $12.3~~At June 30, 2022 and December 31, 2021, $30.6 million and ~~$14.7~~$36.3 million isare included as current in ~~"Accrued liabilities"~~“Accrued liabilities” on our Unaudited Condensed Consolidated Balance Sheets, ~~as of June 30, 2021 and December 31, 2020,~~ respectively. The remainder of the ARO liability as of June 30, ~~2021~~2022 and December 31, ~~2020~~2021 is included in ~~"Other~~“Other long-term ~~liabilities"~~liabilities” on our Unaudited Condensed Consolidated Balance Sheets.

With respect to our AROs, the following table presents our ~~estimate~~forecast of accretion expense for the periods indicated:

Remainder of 2021 $ 4,975
2022 $ 9,384
2023 $ 9,128
2024 $ 9,783
2025 $ 10,487


Remainder of	2022	$	6,291
	2023	$	10,583
	2024	$	9,767
	2025	$	10,469
	2026	$	8,216

Certain of our unconsolidated affiliates have AROs recorded at June 30, 2022 and December 31, 2021 relating to contractual agreements and regulatory requirements. In addition, certain entities that we consolidate have non-controlling interest owners that are responsible for their representative share of future costs of the related ARO liability. These amounts are immaterial to our Unaudited Condensed Consolidated Financial Statements.

7. Equity Investees

We account for our ownership in our joint ventures under the equity method of accounting. The price we pay to acquire an ownership interest in a company may exceed or be less than the underlying book value of the capital accounts we acquire. Such excess cost amounts are included within the carrying values of our equity investees. At June 30, ~~2021~~2022 and December 31, ~~2020,~~2021, the unamortized excess cost amounts totaled ~~$327.6~~$312.8 million and ~~$335.4~~$319.9 million, respectively. We amortize the ~~excess cost~~differences in carrying value as ~~a reduction~~changes in equity earnings.

The following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
Genesis’ share of operating earnings	Genesis’ share of operating earnings	$	18,094	$	16,490	$	42,627	$	34,522	Genesis’ share of operating earnings	$	18,138	$	18,094	$	34,148	$	42,627
Amortization of excess purchase price		(3,872)		(3,872)		(7,745)		(7,745)
Amortization of differences attributable to Genesis’ carrying value of equity investments										Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)		(3,872)		(7,132)		(7,745)
Net equity in earnings	Net equity in earnings	$	14,222	$	12,618	$	34,882	$	26,777	Net equity in earnings	$	14,572	$	14,222	$	27,016	$	34,882
Distributions received (1)	Distributions received (1)	$	21,914	$	18,394	$	51,430	$	38,959	Distributions received(1)	$	18,732	$	21,914	$	37,750	$	51,430

(1) Includes distributions attributable to the period and received during or promptly following such period.

The following tables present the unaudited balance sheets and statements of operations information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) (which we own 64% of and is our most significant equity investment):


	June 30, 2022		December 31, 2021
BALANCE SHEETS DATA:
Assets
Current assets	$	21,115	$	17,827
Fixed assets, net	152,979		160,379
Other assets	11,660		6,186
Total assets	$	185,754	$	184,392
Liabilities and equity
Current liabilities	$	9,121	$	7,668
Other liabilities	232,631		231,970
Equity (Deficit)	(55,998)		(55,246)
Total liabilities and equity	$	185,754	$	184,392

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. ("Poseidon") (which is our most significant equity investment):

June 30,
2021 December 31, 2020
BALANCE SHEET DATA:
Assets
Current assets $ 17,546 $ 30,465
Fixed assets, net 167,764 171,732
Other assets 5,447 4,673
Total assets $ 190,757 $ 206,870
Liabilities and equity
Current liabilities $ 13,649 $ 9,958
Other liabilities 229,836 237,595
Equity (Deficit) (52,728) (40,683)
Total liabilities and equity $ 190,757 $ 206,870


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
INCOME STATEMENT DATA:
STATEMENTS OF OPERATIONS DATA:										STATEMENTS OF OPERATIONS DATA:
Revenues	Revenues	$	33,757	$	30,419	$	76,170	$	63,311	Revenues	$	35,380	$	33,757	$	66,569	$	76,170
Operating income	Operating income	$	24,636	$	21,922	$	56,797	$	45,528	Operating income	$	25,856	$	24,636	$	47,809	$	56,797
Net income	Net income	$	23,610	$	20,636	$	54,755	$	42,219	Net income	$	24,441	$	23,610	$	45,348	$	54,755

~~Poseidon's~~Poseidon’s Revolving Credit Facility

Borrowings under Poseidon’s revolving credit facility, which was amended and restated in March 2019, are primarily used to fund spending on capital projects. The March 2019 credit facility is non-recourse to Poseidon’s owners and secured by substantially all of ~~Poseidon's~~Poseidon’s assets and has a maturity date of March 2024. The March 2019 credit facility contains customary covenants such as restrictions on debt levels, liens, guarantees, mergers, sale of assets and distributions to owners. A breach of any of these covenants could result in acceleration of the maturity date of Poseidon’s debt. Poseidon was in compliance with the terms of its credit agreement for all periods presented in these Unaudited Condensed Consolidated Financial Statements.

8. Intangible Assets

The following table summarizes the components of our intangible assets at the dates indicated:


		June 30, 2021						December 31, 2020							June 30, 2022						December 31, 2021
		Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value			Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Marine contract intangibles	Marine contract intangibles	$	800	$	589	$	211	$	800	$	571	$	229	Marine contract intangibles	$	800	$	625	$	175	$	800	$	607	$	193
Offshore pipeline contract intangibles	Offshore pipeline contract intangibles	158,101		49,233		108,868		158,101		45,073		113,028		Offshore pipeline contract intangibles	158,101		57,554		100,547		158,101		53,394		104,707
Other	Other	33,629		14,761		18,868		29,244		13,759		15,485		Other	42,735		16,757		25,978		37,933		15,770		22,163
Total	Total	$	192,530	$	64,583	$	127,947	$	188,145	$	59,403	$	128,742	Total	$	201,636	$	74,936	$	126,700	$	196,834	$	69,771	$	127,063

Our amortization of intangible assets for the periods presented was as follows:

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Amortization of intangible assets $ 2,580 $ 4,146 $ 5,180 $ 8,262


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Amortization of intangible assets	$	2,577	$	2,580	$	5,165	$	5,180

We estimate that our amortization expense for the next five years will be as follows:


Remainder of	2022	$	6,110
	2023	$	11,983
	2024	$	11,618
	2025	$	11,393
	2026	$	11,093

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~We estimate that our amortization expense for the next five years will be as follows:~~

Remainder of 2021 $ 5,673
2022 $ 11,244
2023 $ 10,976
2024 $ 10,661
2025 $ 10,494

9. Debt

Our obligations under debt arrangements consisted of the following:


		June 30, 2021						December 31, 2020							June 30, 2022						December 31, 2021
		Principal		Unamortized Premium and Debt Issuance Costs		Net Value		Principal		Unamortized Debt Issuance Costs		Net Value			Principal		Unamortized Premium, Discount and Debt Issuance Costs		Net Value		Principal		Unamortized Premium and Debt Issuance Costs		Net Value
Senior secured credit facility-Revolving Loan (1)	Senior secured credit facility-Revolving Loan (1)	$	118,200	$	0	$	118,200	$	643,700	$	0	$	643,700	Senior secured credit facility-Revolving Loan(1)	$	34,600	$	—	$	34,600	$	49,000	$	—	$	49,000
Senior secured credit facility-Term Loan (2)		300,000		2,547		297,453		0		0		0
6.000% senior unsecured notes due 2023		0		0		0		80,859		504		80,355

5.625% senior unsecured notes due 2024	5.625% senior unsecured notes due 2024	341,135		2,534		338,601		341,135		2,963		338,172		5.625% senior unsecured notes due 2024	341,135		1,678		339,457		341,135		2,106		339,029
6.500% senior unsecured notes due 2025	6.500% senior unsecured notes due 2025	534,834		5,046		529,788		534,834		5,639		529,195		6.500% senior unsecured notes due 2025	534,834		3,858		530,976		534,834		4,452		530,382
6.250% senior unsecured notes due 2026	6.250% senior unsecured notes due 2026	359,799		3,799		356,000		359,799		4,189		355,610		6.250% senior unsecured notes due 2026	344,310		2,890		341,420		359,799		3,410		356,389
8.000% senior unsecured notes due 2027	8.000% senior unsecured notes due 2027	1,000,000		7,401		992,599		750,000		13,022		736,978		8.000% senior unsecured notes due 2027	1,000,000		5,809		994,191		1,000,000		6,592		993,408
7.750% senior unsecured notes due 2028	7.750% senior unsecured notes due 2028	720,975		10,474		710,501		720,975		11,269		709,706		7.750% senior unsecured notes due 2028	690,890		8,512		682,378		720,975		9,678		711,297
5.875% Alkali senior secured notes due 2042														5.875% Alkali senior secured notes due 2042	425,000		22,796		402,204		—		—		—
Total long-term debt	Total long-term debt	$	3,374,943	$	31,801	$	3,343,142	$	3,431,302	$	37,586	$	3,393,716	Total long-term debt	$	3,370,769	$	45,543	$	3,325,226	$	3,005,743	$	26,238	$	2,979,505

(1) Unamortized debt issuance costs associated with our ~~senior secured credit facility~~ Revolving Loan, as defined below (included in ~~Other Long Term~~“Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were ~~$5.5~~$3.7 million and ~~$5.8~~$4.7 million as of June 30, ~~2021~~2022 and December 31, ~~2020,~~2021, respectively.

(2) Unamortized debt issuance costs associated with our senior secured credit facility Term Loan, as defined below (included in Senior Secured Credit Facility, net on the Unaudited Condensed Consolidated Balance Sheets), was $2.5 million as of June 30, 2021.

Senior Secured Credit Facility

On April 8, 2021, we entered into the Fifth Amended and Restated Credit Agreement ~~(our "new credit agreement"~~(the “credit agreement”) to replace our Fourth Amended and Restated Credit ~~Agreement. Our new credit agreement~~Agreement, which provides for a $950 million senior secured credit facility, comprised of a revolving loan facility with a borrowing capacity of $650 million (the ~~"Revolving Loan"~~“Revolving Loan”) and a term loan facility of $300 million (the ~~"Term Loan"~~“Term Loan”). We repaid the Term Loan in full on November 17, 2021 with a portion of the proceeds received from our sale of a 36% minority interest in CHOPS (Note 10). The ~~new~~ credit agreement matures on March 15, 2024, subject to extension at our request for one additional year on up to 2two occasions and subject to certain conditions.

On May 17, 2022, we entered into our Second Amendment and Consent to the credit agreement (the “credit agreement amendment”). This credit agreement amendment, among other things, permitted the entry into and performance of the transactions and agreements secured by the ORRI Interests (as defined below) and replaced our existing LIBOR rate based borrowings with Term SOFR rate, which is a forward looking term rate based on SOFR, discussed in further detail below.

At June 30, ~~2021,~~2022, the key terms for rates under our Revolving Loan (which are dependent on our leverage ratio as defined in the ~~new~~ credit ~~agreement) and Term Loan,~~agreement amendment) are as follows:

•~~Revolving Loan:~~ The interest rate on borrowings may be based on an alternate base rate or ~~a Eurodollar rate,~~Term SOFR, at our option. ~~The~~Interest on alternate base rate loans is equal to the sum of (a) the ~~greatest~~highest of (i) the prime rate in effect on such day, (ii) the federal funds effective rate in effect on such day plus 0.5% ~~of 1%~~ and (iii) the ~~LIBOR rate~~Adjusted Term SOFR (as defined in our credit agreement amendment) for a one-month ~~maturity~~tenor in effect on such day plus 1% and (b) the applicable margin. The ~~Eurodollar rate~~Adjusted Term SOFR is equal to the sum of (a) the ~~LIBOR~~Term SOFR rate (as defined in our credit agreement amendment) for such period plus (b) the ~~applicable interest period multiplied by the statutory reserve rate and (b)~~Term SOFR Adjustment of 0.1% plus (c) the applicable margin. The applicable margin varies from 2.25% to 3.75% on ~~Eurodollar~~Term SOFR borrowings and from 1.25% to 2.75% on alternate base rate borrowings, depending on our leverage ratio. Our leverage ratio is recalculated quarterly and in connection with each material acquisition. At June 30, ~~2021,~~2022, the applicable margins on our borrowings were ~~2.75%~~2.50% for alternate base rate borrowings and ~~3.75%~~3.50% for ~~Eurodollar rate~~Term SOFR borrowings based on our leverage ratio.

•Term Loan: The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate and the Eurodollar rates for our Term Loan are calculated consistent with

~~Table of Contents~~

~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~our Revolving Loan discussed above, and the applicable margin is fixed at 3.75% on Eurodollar borrowings and 2.75% on alternate base rate borrowings for the Term Loan.~~

•Letter of credit fee rates range from 2.25% to 3.75% based on our leverage ratio as computed under the credit ~~facility~~agreement and can fluctuate quarterly. At June 30, ~~2021,~~2022, our letter of credit rate was ~~3.75%~~3.50%.

•We pay a commitment fee on the unused portion of the Revolving Loan. The commitment fee rates on the unused committed amount will range from 0.30% to 0.50% per annum depending on our leverage ratio. At June 30, ~~2021,~~2022, our commitment fee rate on the unused committed amount was 0.50%.

•We have the ability to increase the aggregate size of the Revolving Loan by an additional $200 million, subject to lender consent and certain other customary conditions.

Table of Contents

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

At June 30, ~~2021,~~2022, we had ~~$118.2~~$34.6 million outstanding under our Revolving Loan, with ~~$19.6~~$14.3 million of the borrowed amount designated as a loan under the inventory sublimit. Our ~~new~~ credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which ~~$1.3~~$4.5 million was outstanding at June 30, ~~2021.~~2022. Due to the revolving nature of loans under our Revolving Loan, additional borrowings, periodic repayments and re-borrowings may be made until the maturity date. The total amount available for borrowings under our Revolving Loan at June 30, ~~2021~~2022 was ~~$530.5~~$610.9 million, subject to compliance with covenants.

~~At June 30, 2021, we had $300 million borrowed under our Term Loan. Principal repayments on the Term Loan under our new~~ Our credit agreement ~~are as follows:~~does not include a “borrowing base” limitation except with respect to our inventory loans.

Year
Principal Due (1)
2021 $ 15,000
2022 60,000
2023 100,000
2024 125,000

(1) Principal repayments of $15 million are due at the end of each calendar quarter starting December 31, 2021 until December 31, 2022. Principal repayments of $25 million are due at the end of each calendar quarter during 2023, with the remaining balance due at the maturity date of March 15, 2024. We intend to make the scheduled repayments on our Term Loan with the available borrowing capacity under our Revolving Loan.

~~Under our new credit agreement, the permitted maximum consolidated leverage ratio is 5.85x through June 30, 2021, 5.75x through March 31, 2022,~~Alkali Senior Secured Notes Issuance and then 5.50x thereafter. The permitted maximum consolidated senior secured leverage ratio is 2.50x, and the minimum interest coverage ratio is 2.50x for the full term of the agreement. As of June 30, 2021, we were in compliance with the financial covenants contained in our new credit agreement and indentures for our senior unsecured notes indentures as described below.

~~Senior Unsecured Note~~Related Transactions

On ~~January~~ ~~16, 2020, we~~May 17, 2022, Genesis Energy, L.P., through its newly created wholly-owned unrestricted subsidiary, GA ORRI, LLC (“GA ORRI”), issued ~~$750~~$425 million ~~in aggregate~~ principal amount of our ~~7.75%~~5.875% senior ~~unsecured~~secured notes due ~~February 1, 2028~~2042 (the ~~“2028 Notes”~~“Alkali senior secured notes”) to certain institutional investors (the “Notes Offering”), secured by GA ORRI’s fifty-year limited term overriding royalty interest in substantially all of the Alkali Business’ trona mineral leases (the “ORRI Interests”). Interest payments are due ~~February 1 and August 1~~on the last day of each ~~year. That~~quarter with the initial interest payment due on June 30, 2022. The agreement governing the Alkali senior secured notes also requires principal repayments on the last day of each quarter commencing with the first quarter of 2024. Principal repayments totaling $46.2 million are due within the next five years, with the remaining quarterly principal repayments due thereafter through March 31, 2042, as outlined in the agreement governing the Alkali senior secured notes.The issuance generated net proceeds of ~~$736.7~~$408 million, net of the issuance ~~costs incurred.~~discount of $17 million. We ~~used $554.8~~transferred $18.4 million of the net proceeds into a liquidity reserve account owned by GA ORRI to ~~redeem~~be held as collateral for future interest and principal payments as calculated and described in the agreement governing the Alkali senior secured notes, which proceeds held in the reserve account are classified as “Restricted cash” on the Unaudited Condensed Consolidated Balance Sheet.We used a portion of ~~the 6.75% senior unsecured notes due August 1, 2022 (the "2022 Notes") (including principal, accrued interest and tender premium) that were validly tendered, and~~ the remaining net proceeds ~~were used~~from the issuance to fully redeem the outstanding Alkali Holdings preferred units (as defined and further discussed in Note 10) and utilized the remainder to repay a portion of the outstanding borrowings ~~outstanding~~under the credit agreement.

Additionally, on May 17, 2022, as noted above, we entered into our credit agreement amendment. This amendment also designated GA ORRI and its direct parent, GA ORRI Holdings, LLC (“GA ORRI Holdings”), as unrestricted subsidiaries under our ~~revolving~~ credit ~~facility.~~agreement. We also designated GA ORRI and GA ORRI Holdings as unrestricted subsidiaries under the indentures governing our 5.625% senior notes due 2024, 6.50% senior notes due 2025, 6.250% senior notes due 2026, 2027 Notes (defined below) and 7.750% senior notes due 2028. On ~~January~~May 17, ~~2020~~ we ~~called for redemption~~also reclassified the ~~remaining $222.1 million of~~subsidiaries originally held by our ~~2022 Notes,~~Alkali Business as restricted subsidiaries under our credit agreement and ~~they were redeemed on February 16, 2020.~~ ~~We incurred a total loss of approximately $23.5 million relating to~~under the ~~extinguishment of~~indentures governing our 2022 Notes, inclusive of our transactions costs and the write-off of the related unamortized debt issuance costs and discount, which is recorded in "Other income (expense)" in our Unaudited Condensed Consolidated Statements of Operations for the six months ended June 30, 2020.senior unsecured notes.

Senior Unsecured Note Transactions

On December 17, 2020, we issued $750 million in aggregate principal amount of our 8.00% senior unsecured notes due January 15, 2027 (the ~~"2027 Notes"~~“2027 Notes”). Interest payments are due on January 15 and July 15 of each year with the initial interest payment due on July 15, 2021. The issuance generated net proceeds of approximately $737 million, net of issuance costs incurred. We used $316.5 million of the net proceeds to repay the portion of the 6.00% senior unsecured notes due May 15, 2023 (the ~~"2023 Notes"~~“2023 Notes”) (including principal, accrued interest and tender premium) that were validly tendered, and the remaining proceeds were used to repay a portion of the borrowings outstanding under our revolving credit facility. On January 19, 2021, we redeemed the remaining principal balance outstanding on our 2023 Notes of $80.9 million in accordance with the terms and conditions of the indenture governing the 2023 Notes. We incurred a total loss of approximately $1.6 million relating to the extinguishment of our remaining 2023 Notes, inclusive of the redemption fee and the write-off of the related unamortized

~~Table of Contents~~

~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

debt issuance costs, which is recorded in ~~"Other~~“Other income (expense)"” in our Unaudited Condensed Consolidated Statements of Operations for the six months ended June 30, 2021.

On April 22, 2021, we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The notes constitute an additional issuance of our existing 2027 Notes that we issued on December 17, 2020 in an aggregate principal amount of $750 million. The additional $250 million of notes have identical terms as (other than with respect to the issue price) and constitute part of the same series of the 2027 Notes. The $250 million of the 2027 Notes were issued at a premium of 103.75% plus accrued interest from December 17, 2020. We used the net proceeds from the offering for general partnership purposes, including repaying a portion of the revolving borrowings outstanding under our ~~new~~ credit agreement.

During ~~2020,~~2022, we repurchased certain of our senior unsecured notes on the open market and recorded cancellation of

debt income of ~~$18.5 million and $19.7~~$4.7 million for the three and six months ended June 30, ~~2020, respectively.~~2022. These are

recorded within ~~"Other~~“Other income (expense)"” in our Unaudited Consolidated Statements of Operations.

Table of Contents

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

current and future 100% owned domestic subsidiaries (the ~~"Guarantor Subsidiaries"~~“Guarantor Subsidiaries”), except ~~the subsidiaries that hold our Alkali Business, Genesis Free State Pipeline, LLC, Genesis NEJD Pipeline, LLC,~~GA ORRI and GA ORRI Holdings, and certain other subsidiaries. The assets owned by Genesis Free State Pipeline, LLC were sold on October 30, 2020 and the ownership of Genesis NEJD Pipeline LLC's pipeline was transferred in October 2020. Genesis NEJD Pipeline LLC is 100% owned by Genesis Energy, L.P., the parent company. The remaining non-guarantor subsidiaries are indirectly owned by Genesis Crude Oil, L.P., a Guarantor Subsidiary. The Guarantor Subsidiaries largely own the assets, other than the ORRI Interests, that we use to operate our ~~business other than our Alkali Business.~~ business. As a general rule, the assets and credit of our unrestricted subsidiaries are not available to satisfy the debts of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries, and the liabilities of our unrestricted subsidiaries do not constitute obligations of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries except, in the case of Genesis Alkali Holdings Company, LLC ("Alkali Holdings") and Genesis Energy, L.P., to the extent agreed to in the services agreement between Genesis Energy, L.P. and Alkali Holdings dated as of September 23, 2019 (the "Services Agreement").Subsidiaries.

10. Partners’ Capital, Mezzanine Capital and Distributions

At June 30, ~~2021,~~2022, our outstanding common units consisted of 122,539,221 Class A units and 39,997 Class B units. The Class A units are traditional common units in us. The Class B units are identical to the Class A units and, accordingly, have voting and distribution rights equivalent to those of the Class A units, and, in addition, the Class B units have the right to elect all of our board of directors and are convertible into Class A units under certain circumstances, subject to certain exceptions. At June 30, 2022, we had 25,336,778 Class A Convertible Preferred Units outstanding, which are discussed below in further detail.

Distributions

We paid or will pay the following cash distributions to our common unitholders in ~~2020~~2021 and ~~2021:~~2022:


Distribution For	Distribution For	Date Paid		Per Unit Amount		Total Amount		Distribution For	Date Paid		Per Unit Amount		Total Amount
2020

2021								2021
1st Quarter	1st Quarter	May 15, 2020		$	0.15	$	18,387	1st Quarter	May 14, 2021		$	0.15	$	18,387
2nd Quarter	2nd Quarter	August 14, 2020		$	0.15	$	18,387	2nd Quarter	August 13, 2021		$	0.15	$	18,387
3rd Quarter	3rd Quarter	November 13, 2020		$	0.15	$	18,387	3rd Quarter	November 12, 2021		$	0.15	$	18,387
4th Quarter	4th Quarter	February 12, 2021		$	0.15	$	18,387	4th Quarter	February 14, 2022		$	0.15	$	18,387
2021
2022								2022
1st Quarter	1st Quarter	May 14, 2021		$	0.15	$	18,387	1st Quarter	May 13, 2022		$	0.15	$	18,387
2nd Quarter	2nd Quarter	August 13, 2021	(1)	$	0.15	$	18,387	2nd Quarter	August 12, 2022	(1)	$	0.15	$	18,387

(1)This distribution was declared on July ~~7, 2021~~12, 2022 and will be paid to unitholders of record as of July ~~30, 2021.~~29, 2022.

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

Class A Convertible Preferred Units

~~At June 30, 2021 we had 25,336,778 Class A Convertible Preferred Units (our "Class A Convertible Preferred Units") outstanding.~~ Our Class A Convertible Preferred Units rank senior to all of our currently outstanding classes or series of limited partner interests with respect to distribution and/or liquidation rights. Holders of our Class A Convertible Preferred Units vote on an as-converted basis with holders of our common units and have certain class voting rights, including with respect to any amendment to the partnership agreement that would adversely affect the rights, preferences or privileges, or otherwise modify the terms, of those Class A Convertible Preferred Units.

Accounting for the Class A Convertible Preferred Units

Our Class A Convertible Preferred Units are considered redeemable securities under GAAP due to the existence of redemption provisions upon a deemed liquidation event that is outside of our control. Therefore, we present them as temporary equity in the mezzanine section of the Unaudited Condensed Consolidated Balance Sheets. Because our Class A Convertible Preferred Units are not currently redeemable and we do not have plans or expect any events that constitute a change of control in our partnership agreement, we present our Class A Convertible Preferred Units at their initial carrying amount. However, we would be required to adjust that carrying amount if it becomes probable that we would be required to redeem our Class A Convertible Preferred Units.

Initial and Subsequent Measurement

We initially recognized our Class A Convertible Preferred Units at their issuance date fair value, net of issuance costs. We will not be required to adjust the carrying amount of our Class A Convertible Preferred Units until it becomes probable that they would become redeemable. Once redemption becomes probable, we would adjust the carrying amount of our Class A Convertible Preferred Units to the redemption value over a period of time comprising the date the feature first becomes probable and the date the units can first be redeemed. Our Class A Convertible Preferred Units contain a distribution Rate Reset Election (as defined in Note 15). This Rate Reset Election is bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period. Refer to Note 15 and Note 16 for additional discussion.

Net Loss Attributable to Genesis Energy, L.P. is reduced by Class A Convertible Preferred Unit distributions that accumulated during the period. Net Loss Attributable to Genesis Energy, L.P. was reduced by $18.7 million and $37.4 million for the three and six months ended June 30, 2021 and 2020.

~~We paid or will pay the following cash distributions to our Class A Convertible Preferred unitholders in 2020 and 2021:~~

Distribution For Date Paid Per Unit
Amount Total
Amount
2020
1st Quarter
May 15, 2020 $ 0.7374 $ 18,684
2nd Quarter
August 14, 2020 $ 0.7374 $ 18,684
3rd Quarter
November 13, 2020 $ 0.7374 $ 18,684
4th Quarter
February 12, 2021 $ 0.7374 $ 18,684
2021
1st Quarter
May 14, 2021 $ 0.7374 $ 18,684
2nd Quarter
August 13, 2021 (1) $ 0.7374 $ 18,684

~~(1) This distribution was declared on July 7, 2021 and will be paid to unitholders of record as of July 30, 2021.~~

1917

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Net Income (Loss) Attributable to Genesis Energy, L.P. is reduced by Class A Convertible Preferred Unit distributions that accumulated during the period and was reduced by $18.7 million and $37.4 million for the three and six months ended June 30, 2022 and 2021, respectively.

We paid or will pay the following cash distributions to our Class A Convertible Preferred unitholders in 2021 and 2022:


Distribution For	Date Paid		Per Unit Amount		Total Amount





2021
1st Quarter	May 14, 2021		$	0.7374	$	18,684
2nd Quarter	August 13, 2021		$	0.7374	$	18,684
3rd Quarter	November 12, 2021		$	0.7374	$	18,684
4th Quarter	February 14, 2022		$	0.7374	$	18,684
2022
1st Quarter	May 13, 2022		$	0.7374	$	18,684
2nd Quarter	August 12, 2022	(1)	$	0.7374	$	18,684

(1)This distribution was declared on July 12, 2022 and will be paid to unitholders of record as of July 29, 2022.

Redeemable Noncontrolling Interests

On September 23, 2019, we, through a subsidiary, Alkali Holdings, entered into an amended and restated Limited Liability Company Agreement of Alkali Holdings (the ~~"LLC Agreement"~~“LLC Agreement”) and a Securities Purchase Agreement (the ~~"Securities~~“Securities Purchase ~~Agreement"~~Agreement”) whereby certain investment fund entities affiliated with ~~GSO~~Blackstone Alternative Credit Advisors LP, formerly known as “GSO Capital Partners LPLP” (collectively ~~"GSO"~~“BXC”) purchased ~~$55,000,000~~$55.0 million (or 55,000 Alkali Holdings preferred units) and committed to purchase up to ~~$350,000,000~~$350.0 million of Alkali Holdings preferred units, ~~in Alkali Holdings,~~ the entity that holds our trona and trona-based exploring, mining, processing, producing, marketing and selling business, including its Granger facility near Green River, Wyoming. Alkali Holdings ~~will use~~utilized the net proceeds received from the ~~Alkali Holdings~~ preferred units to fund ~~up to 100%~~a portion of the anticipated cost of expansion of the Granger facility (the ~~"Granger~~“Granger Optimization ~~Project"~~Project” or ~~"GOP"~~“GOP”).

On April 14, 2020, we entered into an amendment to our agreements with ~~GSO~~BXC to, among other things, extend the construction timeline of the GOP by one year, which we currently anticipate completing in the ~~second half~~third quarter of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to ~~GSO,~~BXC, which was accounted for as issuance costs. As part of the amendment, the commitment period was increased to four years, and the total commitment of ~~GSO~~BXC was increased to, subject to compliance with the covenants contained in the agreements with ~~GSO,~~BXC, up to ~~$351,750,000~~$351.8 million preferred units (or 351,750 preferred units) in Alkali Holdings.

From time to time after we had drawn at least $251.8 million, we had the option to redeem the outstanding preferred

units in whole for cash at a price equal to the initial $1,000 per preferred unit purchase price, plus no less than the greater of a

predetermined fixed internal rate of return amount (“IRR”) or a multiple of invested capital metric (“MOIC”), net of cash distributions paid to date (“Base Preferred Return Amount”). Additionally, if all outstanding preferred units were redeemed, we had not drawn at least $251.8 million, and BXC was not a “defaulting member” under the LLC Agreement, BXC had the right to a make-whole amount on the number of undrawn preferred units.

On May 17, 2022 (the “Redemption Date”), we fully redeemed the 251,750 outstanding Alkali Holdings preferred units at a Base Preferred Return Amount of $288.6 million utilizing a portion of the proceeds we received from the issuance of our Alkali senior secured notes. As of June 30, ~~2021,~~2022, there ~~are 201,705~~were 0 Alkali Holdings preferred units outstanding.

Accounting for Redeemable Noncontrolling Interests

Classification

~~The~~Prior to the Redemption Date, the Alkali Holdings preferred units issued and outstanding ~~are~~were accounted for as a redeemable noncontrolling interest in the mezzanine section on our Unaudited Condensed Consolidated Balance Sheets due to the redemption features for a change of control.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Initial and Subsequent Measurement

We recorded the Alkali Holdings preferred units at their issuance date fair value, net of issuance costs. The fair value of the Alkali Holdings preferred units was approximately $270.1 million as of ~~June 30, 2021 represents~~May 16, 2022, which represented the carrying amount based on the issued and outstanding Alkali Holdings preferred units most probable redemption event on the six and a half year anniversary of the closing, which iswas the ~~predetermined internal rate of~~ ~~return~~IRR measure accreted using the effective interest method to the redemption value as of ~~the~~each reporting date. On May 16, 2022, certain events occurred that made it probable that an early redemption event on the Alkali Holdings preferred units would occur and the outstanding preferred units would be redeemed at the MOIC, as it was greater than the IRR at the time of the redemption. This required the Company to revalue the Alkali Holdings preferred units to the redemption amount of $288.6 million, which represents the MOIC, net of cash distributions (including tax distributions) paid to date.

Net ~~Loss~~Income (Loss) Attributable to Genesis Energy, L.P. for the three and six months ended June 30, ~~2021~~2022 includes ~~$5.8~~$22.6 million and $30.4 million of adjustments, respectively, of which ~~$4.9~~$3.4 million and $10.0 million, respectively, was allocated to the paid-in-kind ~~("PIK"~~(“PIK”) distributions on the outstanding Alkali Holdings preferred units, $0.7 million and ~~$0.9~~$1.9 million, respectively was attributable to redemption accretion value ~~adjustments.~~ ~~Net Loss Attributable to~~ ~~Genesis Energy, L.P. for the six months ended June 30, 2021 includes $10.6 million of~~ adjustments, ~~of which $9.0 million was allocated to the PIK distributions on the outstanding Alkali Holdings preferred units~~ and ~~$1.6~~$18.5 million was attributable to ~~redemption accretion value adjustments.~~a change in the Base Preferred Return Amount of the Alkali Holdings preferred units. Net Loss Attributable to Genesis Energy, L.P. for the three and six months ended June 30, ~~2020~~2021 includes ~~$4.2~~$5.8 million and $10.6 million of adjustments, respectively, of which ~~$3.4~~$4.9 million and $9.0 million, respectively, was allocated to the PIK distributions and ~~$0.8~~$0.9 million ~~was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the six months ended June 30, 2020 includes $8.2~~and $1.6 million, ~~of adjustments, of which $6.7 million was allocated to the PIK distributions and $1.5 million~~respectively, was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended June 30, ~~2021~~2022 in-kind to our Alkali Holdings preferred unitholders. The unitholders liquidation preference is increased by new issuances and PIK distributions and is reduced by tax distributions paid to the unitholders, which are required to be paid by us to fulfill the income tax liabilities of each holder of Alkali Holdings preferred units.

~~As of the reporting date, there are no triggering, change of control, early redemption or monetization events that are probable that would require us to revalue the Alkali Holdings preferred units.~~

If the Alkali Holdings preferred units were redeemed on the reporting date of June 30, 2021, the redemption amount would be equal to $248.9 million, which would be the multiple of invested capital metric applied to the Alkali Holdings preferred units outstanding plus the make-whole amount on the undrawn minimum Alkali Holdings preferred units.

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

The following table shows the change in our redeemable noncontrolling interest balance from December 31, ~~2020~~2021 to June 30, ~~2021:~~2022:


Balance as of December 31, ~~2020~~2021	$	~~141,194~~259,568
Issuance of preferred units, net of issuance costs(1)	~~59,247~~5,249
PIK distribution	~~8,955~~9,993
Redemption accretion	~~1,602~~1,908
Tax distributions(1)	~~(6,351)~~(6,631)

Adjustment to Base Preferred Return Amount	18,542

Redemption of preferred units on May 17, 2022	(288,629)
Balance as of June 30, ~~2021~~2022	$	~~204,647~~—

(1)During the period ended June 30, ~~2021,~~2022, we issued ~~6,356~~5,356 Alkali Holdings preferred units to ~~GSO~~BXC to satisfy the ~~company's~~Company’s obligation to pay tax distributions. ~~Additionally,~~

Noncontrolling Interests

On November 17, 2021, we, ~~issued 54,100 Alkali Holdings preferred units~~through a subsidiary, sold 36% of the membership interests in CHOPS for proceeds of approximately $418 million. We retained 64% of the membership interests in CHOPS and remain the operator of the CHOPS pipeline and associated assets. We also own an 80% membership interest in Independence Hub, LLC. On April 29, 2022, we entered into an agreement to ~~GSO during~~sell the Independence Hub platform to a producer group in the Gulf of Mexico for gross proceeds of $40 million, of which $8 million, or 20%, is attributable and was paid to our noncontrolling interest holders. For the three and six months ended June 30, ~~2021~~2022, we recognized a gain of $40 million recorded in “Gain on sale of asset” on the Unaudited Condensed Consolidated Statement of Operations, of which $8 million, or 20%, is attributable to ~~continue to fund~~our noncontrolling interest holders, as the ~~GOP.~~

platform asset sold had no book value at the time of the sale. For financial reporting purposes, the assets and liabilities of these entities are consolidated with those of our own, with any third party or affiliate interest in our Unaudited Condensed Consolidated Balance Sheets amounts shown as noncontrolling interests in equity.

11. Net ~~Loss~~Income (Loss) Per Common Unit

Basic net income (loss) per common unit is computed by dividing ~~net income,~~Net Income (Loss) Attributable to Genesis Energy, L.P., after considering income attributable to our Class A preferred unitholders, by the weighted average number of common units outstanding.

The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Under the if-converted method, ~~these units~~the Class A Convertible Preferred Units are assumed to be converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

net income per common unit calculation for the period being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. For the three and six months ended June 30, 2022 and 2021, the effect of the assumed conversion of the 25,336,778 Class A Convertible Preferred Units was anti-dilutive and was not included in the computation of diluted earnings per unit.

The following table reconciles ~~net loss~~Net income (loss) attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net ~~loss~~income (loss) per common unit (in thousands):

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Net Loss Attributable to Genesis Energy L.P. $ (41,682) $ (326,714) $ (75,906) $ (301,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units (18,684) (18,684) (37,368) (37,368)
Net Loss Available to Common Unitholders $ (60,366) $ (345,398) $ (113,274) $ (339,173)
Weighted Average Outstanding Units 122,579 122,579 122,579 122,579
Basic and Diluted Net Loss per Common Unit $ (0.49) $ (2.82) $ (0.92) $ (2.77)


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	35,347	$	(41,682)	$	30,097	$	(75,906)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(37,368)		(37,368)
Net income (loss) attributable to common unitholders	$	16,663	$	(60,366)	$	(7,271)	$	(113,274)

Weighted average outstanding units	122,579		122,579		122,579		122,579

Basic and diluted net income (loss) per common unit	$	0.14	$	(0.49)	$	(0.06)	$	(0.92)

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

12. Business Segment Information

We currently manage our businesses through 4 divisions that constitute our reportable segments:

•Offshore pipeline transportation – offshore transportation of crude oil and natural gas in the Gulf of Mexico;

•Sodium minerals and sulfur services – trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as the processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and the selling of the related by-product, NaHS;

•Onshore facilities and transportation – terminalling, blending, storing, marketing and transporting crude oil and petroleum products (primarily fuel oil, asphalt and other heavy refined products); and

•Marine transportation – marine transportation to provide waterborne transportation of petroleum products (primarily fuel oil, asphalt and other heavy refined products) and crude oil throughout North America.

Substantially all of our revenues are derived from, and substantially all of our assets ~~that~~ are located in, the United States.

We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash gains and charges, such as depreciation, depletion, amortization and accretion), and segment general and administrative expenses, net of the effects of our noncontrolling interests, plus our equity in distributable cash generated by our equity ~~investees.~~investees and unrestricted subsidiaries. In addition, our Segment Margin definition excludes the non-cash effects of our long-term incentive compensation plan and includes the non-income portion of payments received under ~~the~~our previously owned direct financing lease.

Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes, where relevant, and capital investment.

2220

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Segment information for the periods presented below was as follows:


		Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Onshore Facilities & Transportation		Marine Transportation		Total			Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Onshore Facilities & Transportation		Marine Transportation		Total
Three Months Ended June 30, 2022												Three Months Ended June 30, 2022
Segment margin (a)												Segment margin (a)	$	118,980	$	71,701	$	11,018	$	17,573	$	219,272
Capital expenditures (b)												Capital expenditures (b)	$	44,369	$	38,920	$	1,780	$	4,070	$	89,139
Revenues:												Revenues:
External customers												External customers	$	82,085	$	321,192	$	242,131	$	76,317	$	721,725
Intersegment (c)												Intersegment (c)	—		(2,584)		2,581		3		—
Total revenues of reportable segments												Total revenues of reportable segments	$	82,085	$	318,608	$	244,712	$	76,320	$	721,725
Three Months Ended June 30, 2021	Three Months Ended June 30, 2021											Three Months Ended June 30, 2021
Segment margin (a)	Segment margin (a)	$	83,106	$	38,194	$	22,368	$	8,468	$	152,136	Segment margin (a)	$	83,106	$	38,194	$	22,368	$	8,468	$	152,136
Capital expenditures (b)	Capital expenditures (b)	$	19,421	$	80,560	$	2,487	$	11,157	$	113,625	Capital expenditures (b)	$	19,421	$	80,560	$	2,487	$	11,157	$	113,625
Revenues:	Revenues:											Revenues:
External customers	External customers	$	73,221	$	239,258	$	144,406	$	46,970	$	503,855	External customers	$	73,221	$	239,258	$	144,406	$	46,970	$	503,855
Intersegment (c)	Intersegment (c)	0		(2,171)		1,515		656		0		Intersegment (c)	—		(2,171)		1,515		656		—
Total revenues of reportable segments	Total revenues of reportable segments	$	73,221	$	237,087	$	145,921	$	47,626	$	503,855	Total revenues of reportable segments	$	73,221	$	237,087	$	145,921	$	47,626	$	503,855
Three Months Ended June 30, 2020
Segment margin (a)		$	75,148	$	24,824	$	21,215	$	18,138	$	139,325
Capital expenditures (b)		$	1,983	$	33,462	$	829	$	3,493	$	39,767
Six Months Ended June 30, 2022												Six Months Ended June 30, 2022
Segment Margin ~~(a)~~(1)												Segment Margin ~~(a)~~(1)	$	189,884	$	139,076	$	18,054	$	29,710	$	376,724
Capital expenditures(2)												Capital expenditures(2)	$	79,810	$	65,246	$	2,517	$	14,129	$	161,702
Revenues:	Revenues:											Revenues:
External customers	External customers	$	64,964	$	194,543	$	74,690	$	54,270	$	388,467	External customers	$	150,153	$	609,200	$	462,426	$	131,893	$	1,353,672
Intersegment (c)		0		(1,919)		(531)		2,450		0
Intersegment(3)												Intersegment(3)	—		(4,918)		4,717		201		—
Total revenues of reportable segments	Total revenues of reportable segments	$	64,964	$	192,624	$	74,159	$	56,720	$	388,467	Total revenues of reportable segments	$	150,153	$	604,282	$	467,143	$	132,094	$	1,353,672
Six Months Ended June 30, 2021
Six June Months Ended June 30, 2021												Six June Months Ended June 30, 2021
Segment Margin ~~(a)~~(1)	Segment Margin ~~(a)~~(1)	$	167,375	$	81,914	$	43,367	$	15,577	$	308,233	Segment Margin ~~(a)~~(1)	$	167,375	$	81,914	$	43,367	$	15,577	$	308,233
Capital expenditures (b)		$	30,949	$	90,598	$	3,586	$	22,871	$	148,004
Capital expenditures(2)												Capital expenditures(2)	$	30,949	$	90,598	$	3,586	$	22,871	$	148,004
Revenues:	Revenues:											Revenues:
External customers	External customers	$	137,605	$	468,564	$	332,556	$	86,349	$	1,025,074	External customers	$	137,605	$	468,564	$	332,556	$	86,349	$	1,025,074
Intersegment (c)		0		(4,190)		2,582		1,608		0
Intersegment(3)												Intersegment(3)	—		(4,190)		2,582		1,608		—
Total revenues of reportable segments	Total revenues of reportable segments	$	137,605	$	464,374	$	335,138	$	87,957	$	1,025,074	Total revenues of reportable segments	$	137,605	$	464,374	$	335,138	$	87,957	$	1,025,074
Six Months Ended June 30, 2020
Segment Margin ~~(a)~~(1)		$	160,394	$	61,765	$	49,314	$	37,140	$	308,613
Capital expenditures (b)		$	3,010	$	48,437	$	1,986	$	17,725	$	71,158
Revenues:
External customers		$	143,393	$	440,078	$	231,489	$	113,430	$	928,390
Intersegment (c)		0		(4,064)		(1,572)		5,636		0
Total revenues of reportable segments		$	143,393	$	436,014	$	229,917	$	119,066	$	928,390

~~(a)~~(1)A reconciliation of ~~total Segment Margin to net loss~~Net income (loss) attributable to Genesis Energy, L.P. to total Segment Margin for the periods is presented below.

~~(b)~~(2)Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as contributions to equity investees, if any.

~~(c)~~(3)Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Total assets by reportable segment were as follows:

June 30,
2021 December 31, 2020
Offshore pipeline transportation $ 2,152,939 $ 2,187,083
Sodium minerals and sulfur services 2,041,083 1,962,146
Onshore facilities and transportation 1,011,805 1,035,662
Marine transportation 710,870 711,058
Other assets 46,790 37,670
Total consolidated assets $ 5,963,487 $ 5,933,619


	June 30, 2022		December 31, 2021
Offshore pipeline transportation	$	2,142,264	$	2,103,140
Sodium minerals and sulfur services	2,195,737		2,132,588
Onshore facilities and transportation	868,779		923,064
Marine transportation	705,265		703,030
Other assets	59,415		43,979
Total consolidated assets	$	5,971,460	$	5,905,801

Reconciliation of ~~total Segment Margin to net loss~~Net income (loss) attributable to Genesis Energy, L.P.: to total Segment Margin:

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Total Segment Margin $ 152,136 $ 139,325 $ 308,233 $ 308,613
Corporate general and administrative expenses (12,359) (24,867) (23,511) (31,359)
Depreciation, depletion, amortization and accretion (69,684) (82,580) (138,681) (158,558)
Interest expense (59,169) (51,618) (116,998) (106,583)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)
(7,692) (5,776) (16,548) (12,182)
Other non-cash items (2)
(14,683) (23,291) (33,127) 8,777
Distribution from unrestricted subsidiaries not included in income (3)
(17,500) (2,294) (35,000) (4,532)
Cancellation of debt income (4)
0 18,532 0 19,725
Loss on extinguishment of debt (4)
0 0 (1,627) (23,480)
Differences in timing of cash receipts for certain contractual arrangements (5)
(6,446) (11,638) (6,745) (16,128)
Impairment expense (6)
0 (277,495) 0 (277,495)
Provision for leased items no longer in use 6 (58) (598) 72
Redeemable noncontrolling interest redemption value adjustments (7)
(5,766) (4,159) (10,557) (8,245)
Income tax expense (525) (795) (747) (430)
Net loss attributable to Genesis Energy, L.P. $ (41,682) $ (326,714) $ (75,906) $ (301,805)


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	35,347	$	(41,682)	$	30,097	$	(75,906)
Corporate general and administrative expenses	21,105		12,359		36,826		23,511
Depreciation, depletion, amortization and accretion	76,277		69,684		149,225		138,681
Interest expense	55,959		59,169		111,063		116,998
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income(1)	4,160		7,692		10,734		16,548
Other non-cash items(2)	(8,908)		14,683		(12,479)		33,127
Distribution from unrestricted subsidiaries not included in income(3)	32,000		17,500		32,000		35,000
Cancellation of debt income(4)	(4,737)		—		(4,737)		—
Loss on extinguishment of debt(5)	501		—		501		1,627
Differences in timing of cash receipts for certain contractual arrangements(6)	16,477		6,446		24,707		6,745


Change in provision for leased items no longer in use	(100)		(6)		(531)		598
Redeemable noncontrolling interest redemption value adjustments(7)	22,620		5,766		30,443		10,557
Gain on sale of asset, net to our ownership interest(8)	(32,000)		—		(32,000)		—
Income tax expense	571		525		875		747
Total Segment Margin	$	219,272	$	152,136	$	376,724	$	308,233

(1)Includes distributions attributable to the quarter and received during or promptly following such quarter.

(2)The three and six months ended June 30, ~~2021 include a $14.3~~2022 includes unrealized losses of $2.3 million and unrealized ~~loss~~gains of $3.8 million, respectively, from the valuation of our commodity derivative transactions (excluding fair value hedges) and ~~$32.8~~unrealized gains of $10.7 million ~~unrealized loss,~~and $6.4 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and six months ended June 30, ~~2020 include a $21.8~~2021 includes unrealized losses of $14.3 million ~~unrealized loss~~ and ~~$10.7~~$32.8 million, ~~unrealized gain,~~ respectively, from the valuation of the embedded ~~derivative.~~derivative associated with our Class A Convertible Preferred Units. Refer toNote 15 and Note 16 for details.

(3)The three and six months ended June 30, 2022 include $32.0 million in cash receipts associated with the sale of the Independence Hub platform by our 80% owned unrestricted subsidiary (as defined under our credit agreement), Independence Hub, LLC. The three and six months ended June 30, 2021 include $17.5 million and $35.0 million ~~respectively,~~ in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. ~~The three and six months ended June 30, 2020 include $2.3 million and $4.5 million, respectively, in cash receipts not included in income~~We received the final principal payment associated with ~~principal repayments on~~ our previously owned NEJD ~~pipeline.~~pipeline in the fourth quarter of 2021. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit ~~facility. See~~ ~~Note 4~~ ~~for details.~~agreement.

(4)The three and six months ended June 30, 2022 include income associated with the repurchase and extinguishment of certain of our senior unsecured notes on the open market of $4.7 million.

(5)The three and six months ended June 30, 2022 includes the write-off of the unamortized issuance costs associated with the senior unsecured notes that we repurchased and extinguished during the period. The six months ended June 30, 2021 includes the transaction costs associated with redemption of our 2023 Notes, as well as the write-off of the unamortized issuance costs associated with these notes. Refer to Note 9 for ~~details surrounding the repurchases of certain of our senior unsecured notes and the extinguishment of our 2022 Notes and 2023 Notes.~~details.

~~(5)~~ (6)Includes the difference in timing of cash receipts from or billings to customers during the period and the revenue we recognize in accordance with GAAP on our related contracts.

~~(6)~~(7)Includes PIK distributions and accretion on the redemption feature attributable to each period, and valuation adjustments to the redemption feature during the second quarter of 2022. Refer to Note 610 for ~~details surrounding our non-cash impairment expense recorded for the three and six months ended June 30, 2020.~~details.

~~(7) Includes PIK distributions attributable to the period and accretion on the redemption feature.~~

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(8)On April 29, 2022, we sold our Independence HUB Platform and recognized a gain on the sale of $40.0 million, of which $32.0 million was attributable to our 80% ownership interest.

13. Transactions with Related Parties

The transactions with related parties were as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
Revenues:	Revenues:									Revenues:

Revenues from services and fees to Poseidon(1)	Revenues from services and fees to Poseidon(1)	$	3,242	$	3,035	$	7,028	$	6,182	Revenues from services and fees to Poseidon(1)	$	3,860	$	3,242	$	7,098	$	7,028
Revenues from product sales to ANSAC	Revenues from product sales to ANSAC	71,329		48,695		139,284		121,774		Revenues from product sales to ANSAC	97,328		71,329		185,510		139,284

Costs and expenses:	Costs and expenses:									Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft	Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	330	$	330	Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	330	$	330
Charges for services from Poseidon(1)	Charges for services from Poseidon(1)	238		249		478		503		Charges for services from Poseidon(1)	254		238		509		478
Charges for services from ANSAC	Charges for services from ANSAC	519		629		697		1,461		Charges for services from ANSAC	2,340		519		3,185		697

(1)We own a 64% interest in Poseidon.

Our CEO, Mr. Sims, owns an aircraft which is used by us for business purposes in the course of operations. We pay Mr. Sims a fixed monthly fee and reimburse the aircraft management company for costs related to our usage of the aircraft, including fuel and the actual out-of-pocket costs. Based on current market rates for chartering of private aircraft under long-term, priority arrangements with industry recognized chartering companies, we believe that the terms of this arrangement are no worse than what we could have expected to obtain in an arms-length transaction.

Transactions with Unconsolidated Affiliates

Poseidon

We ~~are the operator of Poseidon and~~ provide management, administrative and pipeline operator services to Poseidon under an Operation and Management Agreement. Currently, that agreement automatically renews annually unless terminated by either party (as defined in the agreement). Our revenues for the three and six months ended June 30, ~~2021 reflect~~2022 include $2.4 million and ~~$4.7~~$4.9 million, respectively, ~~associated with this~~of fees we earned through the provision of services under that agreement. Our revenues for the three and six months ended June 30, ~~2020 reflect $2.3~~2021 include $2.4 million and ~~$4.6~~$4.7 million, respectively, of fees we earned through the provision of services under that agreement. At June 30, ~~2021~~2022 and December 31, ~~2020,~~2021, Poseidon owed us ~~$2.9~~$1.5 million and ~~$2.6~~$2.4 million, respectively, for services rendered.

ANSAC

We (through a subsidiary of our Alkali Business) are a member of the American Natural Soda Ash Corp. ~~("ANSAC"~~(“ANSAC”), an organization whose purpose is promoting and increasing the use and sale of natural soda ash and other refined or processed sodium products produced in the U.S. and consumed in specified countries outside of the U.S. Members sell products to ANSAC to satisfy ANSAC’s sales commitments to its customers. ANSAC passes its costs through to its members using a pro rata calculation based on sales. Those costs include sales and marketing, employees, office supplies, professional fees, travel, rent and certain other costs. Those transactions do not necessarily represent arm's length transactions and may not represent all costs we would otherwise incur if we operated our Alkali Business on a stand-alone basis. We also benefit from favorable shipping rates for our direct exports when using ANSAC to arrange for ocean transport.

ANSAC is considered a variable interest entity (VIE) because we experience certain risks and rewards from our relationship with them. As we do not exercise control over ANSAC and are not considered its primary beneficiary, we do not consolidate ANSAC. The ANSAC membership agreement provides that in the event an ANSAC member exits or the ANSAC cooperative is dissolved, the exiting members are obligated for their respective portion of the residual net assets or deficit of the cooperative. As of June 30, ~~2021,~~2022, such amount is not material to us.

Net Sales to ANSAC were $71.3 million and $139.3 million during the three and six months ended June 30, 2021 and were $48.7 million and $121.8 million during the three and six months ended June 30, 2020. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $0.5 million and $0.7 million during the three and six months ended June 30, 2021 and were $0.6 million and $1.5 million during the three and six months ended June 30, 2020.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Net Sales to ANSAC were $97.3 million and $185.5 million, respectively, during the three and six months ended June 30, 2022 and were $71.3 million and $139.3 million, respectively, during the three and six months ended June 30, 2021. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $2.3 million and $3.2 million, respectively, during the three and six months ended June 30, 2022 and were $0.5 million and $0.7 million, respectively, during the three and six months ended June 30, 2021.

Receivables from and payables to ANSAC as of June 30, ~~2021~~2022 and December 31, ~~2020~~2021 are as follows:

June 30, December 31,
2021 2020
Receivables:
ANSAC $ 66,178 $ 43,400
Payables:
ANSAC $ 169 $ 470


	June 30,		December 31,
	2022		2021
Accounts receivable - trade, net:
ANSAC	$	89,923	$	64,799
Accounts payable - trade:
ANSAC	$	2,340	$	116

14. Supplemental Cash Flow Information

The following table provides information regarding the net changes in components of operating assets and liabilities.


		Six Months Ended June 30,					Six Months Ended June 30,
		2021		2020			2022		2021
(Increase) decrease in:	(Increase) decrease in:					(Increase) decrease in:
Accounts receivable	Accounts receivable	$	(77,785)	$	178,509	Accounts receivable	$	(48,267)	$	(77,785)
Inventories	Inventories	21,550		(44,394)		Inventories	(11,604)		21,550
Deferred charges	Deferred charges	9,823		9,240		Deferred charges	34,022		9,823
Other current assets	Other current assets	(4,835)		(9,919)		Other current assets	(960)		(4,835)
Increase (decrease) in:	Increase (decrease) in:					Increase (decrease) in:
Accounts payable	Accounts payable	49,809		(93,080)		Accounts payable	(3,720)		49,809
Accrued liabilities	Accrued liabilities	32,710		(20,838)		Accrued liabilities	4,299		32,710
Net changes in components of operating assets and liabilities	Net changes in components of operating assets and liabilities	$	31,272	$	19,518	Net changes in components of operating assets and liabilities	$	(26,230)	$	31,272

Payments of interest and commitment fees were ~~$78.0~~$114.6 million and ~~$97.8~~$78.0 million for the six months ended June 30, ~~2021~~2022 and June 30, ~~2020,~~2021, respectively. The increase in interest payments during 2022 is primarily related to the timing of interest payments on our senior unsecured notes, specifically our 2027 Notes, as we made an interest payment in January 2022. The first interest payment made on our 2027 Notes was in July 2021. We capitalized interest of ~~$1.4~~$5.9 million and ~~$1.0~~$1.4 million during the six months ended June 30, ~~2021~~2022 and June 30, ~~2020,~~2021, respectively.

At June 30, ~~2021~~2022 and June 30, ~~2020,~~2021, we had incurred liabilities for fixed and intangible asset additions totaling ~~$71.5~~$35.5 million and ~~$25.5~~$71.5 million, respectively, that had not been paid at the end of the ~~quarter, and, therefore,~~quarter. Therefore, these amounts were not included in the caption “Payments to acquire fixed and intangible assets” under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows. The ~~increase in this amount is~~amounts as of June 30, 2022 principally ~~due~~relate to the ~~increase in~~ capital expenditures associated with our GOP ~~which has the ability to be fully financed with our Alkali Holding preferred units, subject to compliance with the covenants contained in the agreements with GSO~~ (Note 10).

and offshore growth capital projects.

15. Derivatives

Commodity Derivatives

We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments ~~(primarily~~(exchange-traded futures, options and ~~options contracts traded on the NYMEX)~~swap contracts) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil, natural gas and petroleum products. Our decision as to whether to designate derivative instruments as fair value hedges for accounting purposes relates to our expectations of the length of time we expect to have the commodity price exposure and our expectations as to whether the derivative contract will qualify as highly effective under accounting guidance in limiting our exposure to commodity price risk. Most of the petroleum products, including fuel oil that we supply, cannot be hedged with a high degree of effectiveness with exchange-traded derivative ~~contracts available on the NYMEX;~~contracts; therefore, we do

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

not designate derivative contracts utilized to limit our price risk related to ~~these~~petroleum products as hedges for accounting purposes. Typically, we utilize crude oil and other petroleum products futures and option contracts to limit our exposure to the effect of fluctuations in petroleum products prices on the future sale of our inventory or commitments to purchase petroleum products, and we recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. The recognition of changes in fair value of the derivative contracts not designated as hedges for accounting purposes can occur in

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore, we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed.

We have designated certain crude oil futures contracts as hedges of crude oil inventory due to our expectation that these contracts will be highly effective in hedging our exposure to fluctuations in crude oil prices during the period that we expect to hold that inventory. We account for these derivative instruments as fair value hedges under the accounting guidance. Changes in the fair value of these derivative instruments designated as fair value hedges are used to offset related changes in the fair value of the hedged crude oil inventory. Any hedge ineffectiveness in these fair value hedges and any amounts excluded from effectiveness testing are recorded as a gain or loss within “Onshore facilities and transportation costs - product costs” in the Unaudited Condensed Consolidated Statements of Operations.

In accordance with ~~NYMEX~~exchange requirements, we fund the margin associated with our exchange-traded commodity derivative ~~contracts traded on the NYMEX.~~contracts. The amount of the margin is adjusted daily based on the fair value of the commodity derivative contracts. ~~The margin~~Margin requirements are intended to mitigate a ~~party's~~party’s exposure to market volatility and ~~the associated contracting party~~counterparty credit risk. We offset fair value amounts recorded for our ~~NYMEX~~exchange-traded derivative contracts against required margin funding ~~as required by the NYMEX~~ in ~~Current~~“Current Assets - ~~Other~~Other” in our Unaudited Condensed Consolidated Balance Sheets.

Additionally, we ~~enter into~~utilize swap arrangements. Our Alkali Business relies on natural gas to generate heat and electricity for operations. We use a combination of commodity price swap contracts, ~~and~~ future purchase contracts and option contracts to manage our exposure to fluctuations in natural gas prices. The swap contracts fix the basis differential between NYMEX Henry Hub and NW Rocky Mountain posted prices. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of ~~the~~natural gas derivative contracts as increases or decreases within “Sodium minerals and sulfur services operating costs” in ~~our cost~~the Unaudited Condensed Consolidated Statements of ~~sales. We had 0 outstanding swap contracts at June 30, 2021.~~Operations.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

At June 30, ~~2021,~~2022, we ~~entered into~~had the following outstanding commodity derivative commodity contracts that were entered into to economically hedge inventory, fixed price purchase commitments or forecasted purchases.

Sell (Short)
Contracts Buy (Long)
Contracts
Designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls) 92 0
Weighted average contract price per bbl $ 70.71 $ 0
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls) 204 10
Weighted average contract price per bbl $ 70.75 $ 72.66
Natural gas futures:
Contract volumes (10,000 MMBTU) 15 15
Weighted average contract price per MMBTU $ 3.55 $ 3.14
Crude oil options:
Contract volumes (1,000 bbls) 8 0
Weighted average premium received/paid $ 5.59 $ 0


	Sell (Short) Contracts		Buy (Long) Contracts
Designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 Bbls)	115		—
Weighted average contract price per Bbl	$	117.88	$	—

Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 Bbls)	122		128
Weighted average contract price per Bbl	$	107.36	$	107.84
Natural gas swaps:
Contract volumes (10,000 MMBtu)	—		230
Weighted average price differential per MMBtu	$	—	$	0.003
Natural gas futures:
Contract volumes (10,000 MMBtu)	93		265
Weighted average contract price per MMBtu	$	7.04	$	4.67









Natural gas options:
Contract volumes (10,000 MMBtu)	84		25
Weighted average premium received/paid	$	0.57	$	0.05

Financial Statement Impacts

Unrealized gains are subtracted from net income and unrealized losses are added to net income in determining cash flows from operating activities. To the extent that we have fair value hedges outstanding, the offsetting change recorded in the fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in the cash margin ~~deposits necessary~~balance required to ~~fund unrealized losses~~maintain our exchange-traded derivative contracts also affect cash flows from operating activities.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following tables reflect the estimated fair value ~~gain (loss)~~ position of our derivatives at June 30, ~~2021~~2022 and December 31, ~~2020:~~2021:

Fair Value of Derivative Assets and Liabilities


		Unaudited Condensed Consolidated Balance Sheets Location	Fair Value					Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
			June 30, 2021		December 31, 2020				June 30, 2022		December 31, 2021
Asset Derivatives:	Asset Derivatives:						Asset Derivatives:
Commodity derivatives - futures and call options (undesignated hedges):
Natural Gas Swap (undesignated hedge)							Natural Gas Swap (undesignated hedge)	Current Assets - Other	135		1,867
Commodity derivatives - futures and put and call options (undesignated hedges):							Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized assets	Gross amount of recognized assets	Current Assets - Other	$	65	$	732	Gross amount of recognized assets	Current Assets - Other	$	4,100	$	310
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(65)		(732)		Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(819)		(310)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives			$	0	$	0
Natural Gas Swap (undesignated hedge)		Current Assets - Other	0		616
Commodity derivatives - futures and call options (designated hedges):
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets							Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	3,281	$	—
Commodity derivatives - futures (designated hedges):							Commodity derivatives - futures (designated hedges):
Gross amount of recognized assets	Gross amount of recognized assets	Current Assets - Other	$	13	$	1,022	Gross amount of recognized assets	Current Assets - Other	$	1,715	$	49
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(13)		(1,022)		Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(407)		(49)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives			$	0	$	0
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets							Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	1,308	$	—
Liability Derivatives:	Liability Derivatives:						Liability Derivatives:
Preferred Distribution Rate Reset Election (2)	Preferred Distribution Rate Reset Election (2)	Other long-term liabilities	(85,154)		(52,372)		Preferred Distribution Rate Reset Election(2)	Other long-term liabilities	(76,817)		(83,210)

Commodity derivatives - futures and call options (undesignated hedges):
Natural Gas Swap (undesignated hedge)							Natural Gas Swap (undesignated hedge)	Current Liabilities -Accrued Liabilities	(810)		(608)
Commodity derivatives - futures and put and call options (undesignated hedges):							Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized liabilities	Gross amount of recognized liabilities	Current Assets - Other (1)	$	(605)	$	(2,114)	Gross amount of recognized liabilities	Current Assets - Other(1)	$	(819)	$	(2,380)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other (1)	605		2,114		Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	819		2,380
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives			$	0	$	0
Commodity derivatives - futures and call options (designated hedges):
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets							Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets		$	—	$	—
Commodity derivatives - futures (designated hedges):							Commodity derivatives - futures (designated hedges):
Gross amount of recognized liabilities	Gross amount of recognized liabilities	Current Assets - Other (1)	$	(267)	$	(3,345)	Gross amount of recognized liabilities	Current Assets - Other(1)	$	(407)	$	(209)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other (1)	267		3,073		Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	407		209
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives			$	0	$	(272)
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets							Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets		$	—	$	—

(1)These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under ~~Current~~“Current Assets - ~~Other.~~Other”.

(2)Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative.

Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists. Accordingly, we also offset derivative assets and liabilities with ~~amounts associated with~~our cash ~~margin.~~margin balance. Our exchange-traded derivatives are transacted through brokerage accounts and are subject to margin requirements as established by the respective exchange. On a daily basis, our account equity (consisting of the sum of our cash margin balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin. As of June 30, 2022, we had a net broker receivable of approximately $1.4 million (consisting of initial margin of $2.8 million decreased by $1.5 million variation margin). As of December 31, 2021, we had a net broker receivable of approximately ~~$1.5~~$2.9 million (consisting of initial margin of ~~$1.5 million and 0 variation margin). As of December 31, 2020, we had a net broker receivable of approximately $3.4 million~~

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

~~(consisting of initial margin of $3.3~~$2.1 million increased by ~~$0.1~~$0.8 million of variation margin). At June 30, ~~2021~~2022 and December 31, ~~2020,~~2021, none of our outstanding derivatives contained credit-risk related contingent features that would result in a material adverse impact to us upon any change in our credit ratings.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Preferred Distribution Rate Reset Election

A derivative feature embedded in a contract that does not meet the definition of a derivative in its entirety must be bifurcated and accounted for separately if the economic characteristics and risks of the embedded derivative are not clearly and closely related to those of the host contract. For a period of 30 days following (i) September 1, 2022 and (ii) each subsequent anniversary thereof, the holders of our Class A Convertible Preferred Units may make a one-time election to reset the quarterly distribution amount (a ~~"Rate~~“Rate Reset ~~Election"~~Election”) to a cash amount per Class A Convertible Preferred Unit equal to the amount that would be payable per quarter if a Class A Convertible Preferred Unit accrued interest on the Issue Price at an annualized rate equal to three-month LIBOR plus 750 basis points; provided, however, that such reset rate shall be equal to 10.75% if (i) such alternative rate is higher than the LIBOR-based rate and (ii) the then market price for our common units is then less than 110% of the Issue Price. The Rate Reset Election of our Class A Convertible Preferred Units represents an embedded derivative that must be bifurcated from the related host contract and recorded at fair value on our Unaudited Condensed Consolidated Balance Sheet. Corresponding changes in fair value are recognized in ~~"Other~~“Other income (expense)"” in our Unaudited Condensed Consolidated Statement of Operations. At June 30, ~~2021,~~2022, the fair value of this embedded derivative was a liability of ~~$85.2~~$76.8 million. See Note 10 for additional information regarding our Class A Convertible Preferred Units and the Rate Reset Election.

Effect on Operating Results


			Amount of Gain (Loss) Recognized in Income										Amount of Gain (Loss) Recognized in Income
		Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended June 30,				Six Months Ended June 30,					Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended June 30,				Six Months Ended June 30,
			2021		2020		2021		2020				2022		2021		2022		2021
Commodity derivatives - futures and call options:	Commodity derivatives - futures and call options:										Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	(1,563)	$	(10,936)	$	(7,460)	$	(10,207)	Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	634	$	(1,563)	$	(536)	$	(7,460)
Contracts not considered hedges under accounting guidance	Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	(1,779)		(2,642)		(5,700)		(4,017)		Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	2,232		(1,779)		8,280		(5,700)
Total commodity derivatives	Total commodity derivatives		$	(3,342)	$	(13,578)	$	(13,160)	$	(14,224)	Total commodity derivatives		$	2,866	$	(3,342)	$	7,744	$	(13,160)

Natural Gas Swap	Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	30	$	983	$	(37)	$	551	Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	(590)	$	30	$	(1,692)	$	(37)

Preferred Distribution Rate Reset Election	Preferred Distribution Rate Reset Election	Other income (expense)	$	(14,344)	$	(21,839)	$	(32,782)	$	10,706	Preferred Distribution Rate Reset Election	Other income (expense)	$	10,651	$	(14,344)	$	6,393	$	(32,782)

16. Fair-Value Measurements

We classify financial assets and liabilities into the following three levels based on the inputs used to measure fair value:

(1)Level 1 fair values are based on observable inputs such as quoted prices in active markets for identical assets and liabilities;

(2)Level 2 fair values are based on pricing inputs other than quoted prices in active markets for identical assets and liabilities and are either directly or indirectly observable as of the measurement date; and

(3)Level 3 fair values are based on unobservable inputs in which little or no market data exists.

As required by fair value accounting guidance, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

Our assessment of the significance of a particular input to the fair value requires judgment and may affect the placement of assets and liabilities within the fair value hierarchy levels.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, ~~2021~~2022 and December 31, ~~2020.~~2021.


		Fair Value at						Fair Value at
		June 30, 2021						December 31, 2020							June 30, 2022						December 31, 2021
Recurring Fair Value Measures	Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3		Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Commodity derivatives:	Commodity derivatives:													Commodity derivatives:
Assets	Assets	$	78	$	0	$	0	$	1,754	$	616	$	0	Assets	$	5,815	$	135	$	—	$	359	$	1,867	$	—
Liabilities	Liabilities	$	(872)	$	0	$	0	$	(5,459)	$	0	$	0	Liabilities	$	(1,226)	$	(810)	$	—	$	(2,589)	$	(608)	$	—
Preferred Distribution Rate Reset Election	Preferred Distribution Rate Reset Election	$	0	$	0	$	(85,154)	$	0	$	0	$	(52,372)	Preferred Distribution Rate Reset Election	$	—	$	—	$	(76,817)	$	—	$	—	$	(83,210)

Rollforward of Level 3 Fair Value Measurements

The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3:


	Six Months Ended June 30,
	~~2021~~
Balance as of December 31, ~~2020~~2021	$	~~(52,372)~~(83,210)
~~Unrealized loss~~Net gain for the period included in earnings	~~(32,782)~~6,393

Balance as of June 30, ~~2021~~2022	$	~~(85,154)~~(76,817)

Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy. The fair value of the swaps contracts was determined using market price quotations and a pricing model. The swap contracts were considered a level 2 input in the fair value hierarchy at June 30, ~~2021.~~2022.

The fair value of the embedded derivative feature is based on a valuation model that estimates the fair value of our Class A Convertible Preferred Units with and without a Rate Reset Election. This model contains inputs, including our common unit price relative to the issuance price, the current dividend yield, the discount yield (which is adjusted periodically for relevant changes associated with the industry’s credit ~~spread,~~markets), default probabilities, equity volatility, U.S. Treasury yields and timing estimates which involve management judgment. Our equity volatility rate used to value our embedded derivative feature was 50% at June 30, ~~2021.~~2022. A significant increase or decrease in the value of these inputs could result in a material change in fair value to this embedded derivative feature. Due to an increase in our discount yield compared to the preceding quarter and December 31, 2021, we recorded an unrealized gain of $10.7 million and $6.4 million, respectively, for the three and six months ended June 30, 2022. Due to a decrease in our discount yield compared to the preceding quarters, ~~as well as the passage of time as we draw nearer to our coupon rate reset date in 2022,~~ we recorded an unrealized ~~losses~~loss of $14.3 million and $32.8 million, respectively, for the three and six months ended June 30, 2021. During the second quarter of 2020, we recorded an unrealized loss of $21.8 million, while in the first quarter of 2020, we recorded an unrealized gain of $32.5 million, due to the significant changes and fluctuations in the energy industry credit markets and our common unit price during the period. These effects are all recorded within ~~"Other~~“Other income (expense)"” on the Unaudited Condensed Consolidated Statements of Operations.

See Note 15 for additional information on our derivative instruments.

Other Fair Value Measurements

We believe the debt outstanding under our senior secured credit facility approximates fair value as the stated rate of interest approximates current market rates of interest for similar instruments with comparable maturities. At June 30, ~~2021~~2022 our senior unsecured notes had a carrying value of approximately $2.9 billion and a fair value of ~~$3.0~~approximately $2.6 billion compared to a carrying value ~~of $2.8 billion~~ and fair value of ~~$2.7~~approximately $3.0 billion at December 31, ~~2020.~~2021. The fair value of the senior unsecured notes is determined based on trade information in the financial markets of our public debt and is considered a Level 2 fair value measurement.

17. Commitments and Contingencies

We are subject to various environmental laws and regulations. Policies and procedures are in place to aid in monitoring compliance and detecting and addressing releases of crude oil from our pipelines or other facilities and from our mining operations relating to our Alkali Business; however, no assurance can be made that such environmental releases may not substantially affect our business.

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~~GENESIS ENERGY, L.P.~~

~~NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS~~

We are subject to lawsuits in the normal course of business and examination by tax and other regulatory authorities. We do not expect such matters presently pending to have a material effect on our financial position, results of operations, or cash flows.

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

The following information should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and accompanying notes included in this Quarterly Report on Form 10-Q. The following information and such Unaudited Condensed Consolidated Financial Statements should also be read in conjunction with the audited financial statements and related notes, together with our discussion and analysis of financial position and results of operations, included in our Annual Report.

Included in Management’s Discussion and Analysis of Financial Condition and Results of Operations are the following sections:

•Overview

•Results of Operations

•Liquidity and Capital Resources

•Guarantor Summarized Financial Information

•Non-GAAP Financial Measures

•Commitments and Off-Balance Sheet Arrangements

•Forward Looking Statements

Overview

We reported Net Income Attributable to Genesis Energy, L.P. of $35.3 million during the three months ended June 30, 2022 (the “2022 Quarter”) compared to Net Loss Attributable to Genesis Energy, L.P. of $41.7 million during the three months ended June 30, 2021 (the ~~"2021 Quarter") compared to Net Loss Attributable to Genesis Energy, L.P. of $326.7 million during the three months ended June 30, 2020 (the "2020 Quarter"~~“2021 Quarter”).

Net ~~Loss~~Income Attributable to Genesis Energy, L.P. in the ~~2020~~2022 Quarter was ~~negatively~~ impacted ~~by impairment expense~~primarily by: (i) an increase in our Segment Margin of ~~$277.5~~$67.1m, inclusive of the $32 million in proceeds received associated with the ~~rail logistics assets included within~~sale of our ~~onshore facilities and transportation segment and a one-time charge~~80% owned Independence Hub platform asset (see “Results of approximately $13 million associated with certain severance and restructuring costs included within general and administrative costs and expenses. Additionally, the 2020 Quarter included cancellation of debt income of $18.5 million, which is recorded within "Other income (expense)"Operations” below for additional details on the ~~Unaudited Condensed Consolidated Statements of Operations, associated with the open market repurchase and extinguishment of certain~~results of our ~~senior unsecured notes.~~

Net Loss Attributable to Genesis Energy, L.P. in the 2021 Quarter was impacted, relative to the 2020 Quarter, by: (i) lower depreciation, depletion and amortization expense of $12.6 million primarily due to lower depreciation expense on our rail logistics assets as they were impaired during 2020;operating segments); (ii) an unrealized (non-cash) ~~loss~~gain from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units of ~~$14.3~~$10.7 million in the ~~2021~~2022 Quarter compared to an unrealized (non-cash) loss of ~~$21.8~~$14.3 million during the ~~2020~~2021 Quarter recorded within ~~Other~~“Other income (expense)”; and (iii) ~~higher interest expense~~cancellation of ~~$7.6~~debt income recognized during the 2022 Quarter of $4.7 million associated with the open market repurchase and extinguishment of certain of our senior unsecured notes. These increases during the 2022 Quarter were partially offset by an increase in income attributable to our redeemable noncontrolling interests by $16.9 million and an increase in general and administrative costs by $7.8 million during the 2022 Quarter (see ~~"Other~~“Other Costs, Interest, and Income ~~Taxes"~~Taxes” below for additional discussion regarding ~~interest expense)~~general and administrative costs).

Cash flow from operating activities was $104.0 million for the 2022 Quarter compared to $111.0 million for the 2021 ~~Quarter compared to $62.6 million for the 2020~~ Quarter. ~~This increase~~The decrease in cash flow from operating activities is primarily attributable to ~~higher Segment Margin of $12.8 million in the 2021 Quarter and positive~~ changes in working ~~capital.~~capital between the two periods offset by an increase in our Segment Margin. See Note 14 in our Unaudited Condensed Consolidated Financial Statements for information regarding changes in working capital during the 2022 Quarter and 2021 Quarter.

Available Cash before Reserves (as defined below in ~~"Non-GAAP~~“Non-GAAP Financial ~~Measures"~~Measures”) to our common unitholders was ~~$49.6~~$121.2 million for the ~~2021~~2022 Quarter, ~~a decrease~~an increase of ~~$0.8~~$71.6 million, or ~~1.7%~~145%, from the ~~2020 Quarter.~~2021 Quarter primarily as a result of our increase in Segment Margin discussed in more detail below. See “Non-GAAP Financial Measures” below for additional information on Available Cash before Reserves.

Segment Margin (as defined below in ~~"Non-GAAP~~“Non-GAAP Financial ~~Measures"~~Measures”) was ~~$152.1~~$219.3 million for the ~~2021~~2022 Quarter, an increase of ~~$12.8~~$67.1 million, or 9%44%, from the ~~2020~~2021 Quarter. A more detailed discussion of our segment results and other costs are included below in ~~"Results~~“Results of ~~Operations"~~Operations”.

See “Non-GAAP Financial Measures” below for additional information on Available Cash before Reserves and Segment Margin.

Distribution to Unitholders

On May 13, 2022, we paid a distribution of $0.15 per unit related to the first quarter of 2022.

In July ~~2021,~~2022, we declared our quarterly distribution to our common unitholders of $0.15 per unit related to the ~~2021~~2022 Quarter. With respect to our Class A Convertible Preferred Units, we declared a quarterly cash distribution of $0.7374 per Class A Convertible Preferred Unit (or $2.9496 on an annualized basis) for each Class A Convertible Preferred Unit held of record. These distributions will be payable on August ~~13, 2021~~12, 2022 to unitholders of record at the close of business on July ~~30, 2021.~~

29, 2022.

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Covid-19, Ukraine War and Market Update

In March 2020, the World Health Organization categorized Covid-19 as a pandemic, and the President of the United States declared the Covid-19 outbreak a national emergency. ~~Our operations, which fall within~~The Covid-19 pandemic, including the ~~energy, mining and transportation sectors, are considered critical and essential by the Department~~outbreak of ~~Homeland Security's CISA and we have~~several variants, has caused continued ~~to operate our assets during this pandemic.~~

We have a designated internal management team to provide resources, updates, and support to our entire workforce during this pandemic, while maintaining a focus to ensure the safety and well-being of our employees, the families of our employees, and the communitiesvolatility in which our businesses operate. We will continue to act in the best interests of our employees, stakeholders, customers, partners, and suppliers and make any necessary changes as required by federal, state, or local authorities as we continue to actively monitor the situation.

~~Beginning in March 2020, Covid-19 caused~~ commodity prices ~~to decline~~ due to, among other things, reduced industrial activity and travel ~~demand.~~demand, varying worldwide restrictions and the timing of closing and re-opening of economies throughout the last two years. Additionally, ~~actions taken by OPEC~~the Russian invasion of Ukraine beginning in February 2022 and ~~other oil exporting nations~~the ongoing war in ~~that timeframe~~Ukraine has caused additional ~~declines and~~ volatility in ~~the price of oil and gas.~~commodity prices. While we have seen ~~some~~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 from the war in Ukraine, there is still an element of volatility that we expect to continue at least for the near-term and possibly longer, due to the ~~continued~~ uncertainty of the pandemic ~~which~~and the war in Ukraine. This volatility could ~~further~~ negatively impact future prices for oil, natural gas, ~~and~~ petroleum products and industrial products.

Due to the economic effects from commodity prices and Covid-19, demand and volumes throughout our businesses were negatively impacted throughout 2020 beginning in the second quarter. Additionally, during 2020, our businesses were negatively impacted by lower refinery utilization, crude differentials, supply and demand imbalances in our Alkali Business, and an unprecedented hurricane season. However, we began to see economic recovery across a majority of our asset footprint as we exited 2020, which has continued during 2021. Specifically, during 2021, our offshore pipeline transportation segment experienced volumes at its normal run rate as we resumed normal operations on our CHOPS pipeline. Additionally, our Alkali Business has continued to see volume demand recovery and continued pricing recovery on our ANSAC export volumes.

We will continue to monitor the market environment and will evaluate whether ~~any~~additional triggering events would indicate possible impairments of long-lived assets, intangible assets and goodwill. Management’s estimates are based on numerous assumptions about future operations and market conditions, which we believe to be reasonable but are inherently uncertain. The uncertainties underlying our assumptions ~~and~~could cause our estimates ~~could~~to differ significantly from actual results, including with respect to the duration and severity of the Covid-19 ~~pandemic.~~pandemic and the war in Ukraine. In the current volatile economic environment and to the extent conditions deteriorate, we may identify triggering events that may require future evaluations of the recoverability of the carrying value of our long-lived assets, intangible assets and goodwill, which could result in impairment charges that could be material to our results of operations.

WeAlthough the ultimate impacts of Covid-19 and the war in Ukraine are still unknown at this time, we believe the fundamentals of our core businesses continue to remain strong and, given the current industry environment and capital market behavior, we have continued our focus on ~~de-leveraging~~deleveraging our balance sheet ~~which included the reduction of our distribution to common unitholders beginning~~as further explained in the first quarter of 2020 and continuing to recognize the benefits from our cost savings initiative in the second quarter of 2020. Additionally, during the 2021 Quarter, we successfully refinanced and extended our senior secured credit facility and issued an additional $250 million in aggregate principal amount of our 2027 Notes. These two events resulted in no scheduled maturities of long-term debt until 2024, other than the minimal quarterly payments due on the Term Loan under our new credit agreement beginning at the end of 2021 (which will be financed by the available borrowing capacity under the Revolving Loan under our new credit agreement). Refer to "Liquidity“Liquidity and Capital ~~Resources" for additional discussion.~~

Resources”.

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Results of Operations

Revenues and Costs and Expenses

Our revenues for the ~~2021~~2022 Quarter increased ~~$115.4~~$217.9 million, or ~~30%~~43%, from the ~~2020~~2021 Quarter and our total costs and expenses (excluding ~~impairment expense)~~the gain on sale of assets) as presented on the Unaudited Condensed Consolidated Statements of Operations increased ~~$89.1~~$186.8 million, or ~~23%~~39%, between the two ~~periods, with a net increase to our operating income of $26.3 million.~~

periods. The increase in our operating income during the ~~2021~~2022 Quarter is primarily driven ~~by: (i) lower~~by higher export pricing and corresponding revenues in our Alkali Business, which is included within our sodium mineral and sulfur services segment, and higher revenues in our offshore transportation segment. These increases are partially offset by higher general and administrative costs ~~as the 2020 Quarter included a one-time charge of approximately $13 million associated with certain severance~~due to increased transaction costs and ~~restructuring costs; and (ii) lower~~higher depreciation, depletion, and amortization ~~of $12.6 million primarily due to lower depreciation~~ expense ~~on our rail logistics assets as they were impaired~~ during ~~2020.~~the 2022 Quarter (see “Other Costs, Interest, and Income Taxes” below for additional discussion).

A substantial portion of our revenues and costs are derived from the purchase and sale of crude oil in our crude oil marketing business, which is included in our onshore facilities and transportation segment, and revenues and costs associated with our Alkali Business, which is included in our sodium minerals and sulfur services segment. We describe, in more detail, the impact on revenues and costs for each of our businesses below.

As it relates to our crude oil marketing business, the average closing prices for West Texas Intermediate crude oil on the New York Mercantile Exchange ~~("NYMEX"~~(“NYMEX”) increased to $108.83 per barrel in the 2022 Quarter, as compared to $66.07 per barrel in the 2021 ~~Quarter, as compared to $27.85 per barrel in the 2020~~ Quarter. ~~Impacts from Covid-19 along with actions taken by OPEC and other oil exporting nations beginning in early 2020 have caused significant and continued price volatility in oil and gas prices.~~

We would expect changes in crude oil prices to continue to proportionately affect our revenues and costs attributable to our purchase and sale of crude oil and petroleum products, producing minimal direct impact on Segment Margin, ~~net income,~~Net loss and Available Cash before Reserves. We have limited our direct commodity price exposure related to crude oil and petroleum products through the broad use of fee-based service contracts, back-to-back purchase and sale arrangements and hedges. As a result, changes in the price of crude oil would proportionately impact both our revenues and our costs, with a disproportionately smaller net impact on our Segment Margin. However, we do have some indirect exposure to certain changes in prices for oil, natural gas and petroleum products, particularly if they are significant and extended. We tend to experience more demand for certain of our services when commodity prices increase significantly over extended periods of time, and we tend to experience less demand for certain of our services when commodity prices decrease significantly over extended periods of time. For additional information regarding certain of our indirect exposure to commodity prices, see our segment-by-segment analysis below and the section of our Annual Report entitled "“ Risks Related to Our Business."”

As it relates to our Alkali Business, our revenues are derived from the extraction of trona, as well as the activities surrounding the processing and sale of natural soda ash and other alkali specialty products, including sodium sesquicarbonate (S-Carb) and sodium bicarbonate (Bicarb), and are a function of our selling prices and volume sold. We sell our products to an industry-diverse and worldwide customer base. Our selling prices are contracted at various times throughout the year and for different durations. Our selling prices for volumes sold internationally and through ANSAC are contracted for the current year either annually in the prior ~~December and January of~~year or periodically throughout the current year ~~or periodically~~ (often quarterly) ~~throughout the current year,~~, and our volumes priced and sold domestically are contracted at various times and can be of varying durations, often multi-year terms. Our sales volumes can fluctuate from period to period and are dependent upon many factors, of which the main drivers are the global market, customer demand and economic growth. Positive or negative changes to our revenue, through fluctuations in sales volumes or selling prices, can have a direct impact to Segment Margin, ~~net~~Net income (loss) and Available Cash before Reserves as these fluctuations may have a lesser impact to operating costs due to the fact that a portion of our costs are fixed in nature. Our costs, of which some are variable in nature and others are fixed in nature, relate primarily to the processing and producing of soda ash (and other alkali specialty products) and marketing and selling activities. In addition, costs include activities associated with mining and extracting trona ore, including energy costs and employee compensation. In our Alkali Business, during the ~~2021~~2022 Quarter as noted above, we had positive effects to our revenues (with a lesser impact to costs) relative to the ~~2020~~2021 Quarter due to ~~increased sales volumes and more~~ favorable ANSAC ~~pricing.~~pricing on our export tons. For additional information, see our segment-by-segment analysis below.

In addition to our crude oil marketing business and Alkali Business discussed above, we continue to operate in our other core businesses including: (i) our offshore Gulf of Mexico crude oil and natural gas pipeline transportation and handling operations, focusing on providing a suite of services primarily to integrated and large independent energy companies who make intensive capital investments (often in excess of a billion dollars) to develop ~~numerous large-reservoir,~~large reservoir, long-lived crude oil and natural gas properties; (ii) our sulfur services business, which is one of the largest producers and marketers (based on tons produced) of NaHS in North and South America; and (iii) our onshore-based refinery-centric operations located primarily in the Gulf Coast region of the U.S., which focus on providing a suite of services primarily to refiners. Refiners are the shippers of over 95% of the volumes transported on our onshore crude pipelines, and refiners ~~contract~~contracted for ~~75%~~approximately 90% of the ~~use of~~revenues from our marine inland barges during the 2022 Quarter, which are used primarily to transport intermediate refined products (not crude oil) between refining complexes. The shippers on our offshore pipelines are mostly integrated and large independent energy companies whose production is ideally

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suited for the vast majority of refineries along the Gulf Coast, unlike the lighter crude oil and condensates produced from numerous onshore shale plays. Their large-reservoir properties and the related pipelines and other infrastructure needed to develop them are capital intensive and yet, we believe, economically viable, in most cases, even in ~~relatively low~~

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volatile commodity price environments. Given these facts, we do not expect changes in commodity prices to impact our ~~net~~Net income (loss), Available Cash before Reserves or Segment Margin derived from our offshore Gulf of Mexico crude oil and natural gas pipeline transportation and handling operations in the same manner in which they impact our revenues and costs derived from the purchase and sale of crude oil and petroleum products.

Additionally, changes in certain of our operating costs between the respective quarters, such as those associated with our sodium minerals and sulfur services, offshore pipeline and marine transportation segments, are not correlated with crude oil prices. We discuss certain of those costs in further detail below in our segment-by-segment analysis.

Segment Margin

The contribution of each of our segments to total Segment Margin was as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
Offshore pipeline transportation	Offshore pipeline transportation	$	83,106	$	75,148	$	167,375	$	160,394	Offshore pipeline transportation	$	118,980	$	83,106	$	189,884	$	167,375
Sodium minerals and sulfur services	Sodium minerals and sulfur services	38,194		24,824		81,914		61,765		Sodium minerals and sulfur services	71,701		38,194		139,076		81,914
Onshore facilities and transportation	Onshore facilities and transportation	22,368		21,215		43,367		49,314		Onshore facilities and transportation	11,018		22,368		18,054		43,367
Marine transportation	Marine transportation	8,468		18,138		15,577		37,140		Marine transportation	17,573		8,468		29,710		15,577
Total Segment Margin	Total Segment Margin	$	152,136	$	139,325	$	308,233	$	308,613	Total Segment Margin	$	219,272	$	152,136	$	376,724	$	308,233

We define Segment Margin as revenues less product costs, operating expenses and segment general and administrative expenses ~~after eliminating gain or loss on sale~~(all of ~~assets,~~which are net of the effects of our noncontrolling interest holders), plus or minus applicable Select ~~Items.~~Items (defined below). Although we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. See ~~"Non-GAAP~~“Non-GAAP Financial ~~Measures"~~Measures” for further discussion surrounding total Segment Margin.

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A reconciliation of ~~total Segment Margin to~~ Net ~~Loss~~Income (Loss) Attributable to Genesis Energy, L.P. to total Segment Margin for the periods presented is as follows:

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
Total Segment Margin $ 152,136 $ 139,325 $ 308,233 $ 308,613
Corporate general and administrative expenses (12,359) (24,867) (23,511) (31,359)
Depreciation, depletion, amortization and accretion (69,684) (82,580) (138,681) (158,558)
Interest expense (59,169) (51,618) (116,998) (106,583)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)
(7,692) (5,776) (16,548) (12,182)
Other non-cash items (2)
(14,683) (23,291) (33,127) 8,777
Distribution from unrestricted subsidiaries not included in income (3)
(17,500) (2,294) (35,000) (4,532)
Cancellation of debt income — 18,532 — 19,725
Provision for leased items no longer in use 6 (58) (598) 72
Differences in timing of cash receipts for certain contractual arrangements (4)
(6,446) (11,638) (6,745) (16,128)
Loss on debt extinguishment (5)
— — (1,627) (23,480)
Impairment expense — (277,495) — (277,495)
Redeemable noncontrolling interest redemption value adjustments (6)
(5,766) (4,159) (10,557) (8,245)
Income tax expense (525) (795) (747) (430)
Net Loss Attributable to Genesis Energy, L.P. $ (41,682) $ (326,714) $ (75,906) $ (301,805)


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Net Income (Loss) Attributable to Genesis Energy, L.P.	$	35,347	$	(41,682)	$	30,097	$	(75,906)
Corporate general and administrative expenses	21,105		12,359		36,826		23,511
Depreciation, depletion, amortization and accretion	76,277		69,684		149,225		138,681
Interest expense	55,959		59,169		111,063		116,998
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income(1)	4,160		7,692		10,734		16,548
Other non-cash items(2)	(8,908)		14,683		(12,479)		33,127
Distributions from unrestricted subsidiaries not included in income(3)	32,000		17,500		32,000		35,000
Change in provision for leased items no longer in use	(100)		(6)		(531)		598
Differences in timing of cash receipts for certain contractual arrangements(4)	16,477		6,446		24,707		6,745

Cancellation of debt income(5)	(4,737)		—		(4,737)		—
Loss on debt extinguishment(6)	501		—		501		1,627

Redeemable noncontrolling interest redemption value adjustments(7)	22,620		5,766		30,443		10,557
Gain on sale of asset, net to our ownership interest(8)	(32,000)		—		(32,000)		—
Income tax expense	571		525		875		747
Total Segment Margin	$	219,272	$	152,136	$	376,724	$	308,233

(1)Includes distributions attributable to the quarter and received during or promptly following such quarter.

(2)The three and six months ended June 30, ~~2021~~2022 include ~~a $14.3~~unrealized losses of $2.3 million and unrealized ~~loss~~gains of $3.8 million, respectively from the valuation of our commodity derivative transactions (excluding fair value hedges) and ~~a $32.8~~unrealized gains of $10.7 million ~~unrealized loss,~~and $6.4 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and six months ended June 30, ~~2020 include a $21.8~~2021 includes unrealized losses of $14.3 million ~~unrealized loss~~ and ~~$10.7~~$32.8 million, ~~unrealized gain,~~ respectively, from the valuation of the embedded ~~derivative.~~derivative associated with our Class A Convertible Preferred Units.

(3)The three and six months ended June ~~30,2021~~30, 2022 include $32.0 million in cash receipts associated with the sale of the Independence Hub platform by our 80% owned unrestricted subsidiary (as defined under our credit agreement), Independence Hub, LLC. The three and six months ended June 30, 2021 include $17.5 million and $35.0 million ~~respectively, and the three and six months ended June 30,2020 include $2.3 million and $4.5 million, respectively,~~ in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. We received the final principal payment associated with our previously owned NEJD pipeline in the fourth quarter of 2021. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit ~~facility.~~agreement.

(4)Includes the difference in timing of cash receipts from or billings to customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

(5)The three and six months ended June 30, ~~2021 includes~~2022 include income associated with the ~~transaction costs~~repurchase and extinguishment of certain of our senior unsecured notes on the open market of $4.7 million.

(6)The three and six months ended June 30, 2022 include the write-off of the unamortized issuance costs associated with the ~~redemption of our remaining 2023 Notes.~~senior unsecured notes that we repurchased and extinguished during the period. The six months ended June 30, ~~2020 includes~~2021 include the transaction costs associated with ~~the tender and~~ redemption of our ~~2022~~2023 Notes, as well as the write-off of the unamortized issuance costs ~~and discount~~ associated with these notes.

~~(6)~~ (7)Includes PIK distributions ~~attributable to the period~~ and accretion on the redemption ~~feature.~~feature attributable to each period, and valuation adjustments to the redemption feature during the 2022 Quarter.

(8)On April 29, 2022, we sold our Independence HUB platform and recognized a gain on the sale of $40.0 million, of which $32.0 million was attributable to our 80% ownership interest.

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Offshore Pipeline Transportation Segment

Operating results and volumetric data for our offshore pipeline transportation segment are presented below:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
Offshore crude oil pipeline revenue, excluding non-cash revenues		$	70,153	$	61,003	$	132,815	$	130,584
Offshore crude oil pipeline revenue, net to our ownership interest and excluding non-cash revenues										Offshore crude oil pipeline revenue, net to our ownership interest and excluding non-cash revenues	$	76,056	$	70,153	$	136,924	$	132,815
Offshore natural gas pipeline revenue, excluding non-cash revenues	Offshore natural gas pipeline revenue, excluding non-cash revenues	10,567		10,302		20,964		23,639		Offshore natural gas pipeline revenue, excluding non-cash revenues	13,439		10,567		22,508		20,964
Offshore pipeline operating costs, excluding non-cash expenses		(19,328)		(14,010)		(37,334)		(31,742)
Distributions from equity investments (1)		21,714		17,853		50,930		37,913
Offshore pipeline operating costs, net to our ownership interest and excluding non-cash expenses										Offshore pipeline operating costs, net to our ownership interest and excluding non-cash expenses	(20,247)		(19,328)		(37,523)		(37,334)
Distributions from unrestricted subsidiaries(1)										Distributions from unrestricted subsidiaries(1)	32,000		—		32,000		—
Distributions from equity investments(2)										Distributions from equity investments(2)	17,732		21,714		35,975		50,930
Offshore pipeline transportation Segment Margin	Offshore pipeline transportation Segment Margin	$	83,106	$	75,148	$	167,375	$	160,394	Offshore pipeline transportation Segment Margin	$	118,980	$	83,106	$	189,884	$	167,375

Volumetric Data 100% basis:	Volumetric Data 100% basis:									Volumetric Data 100% basis:
Crude oil pipelines (average barrels/day unless otherwise noted):	Crude oil pipelines (average barrels/day unless otherwise noted):									Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS	CHOPS	204,963		196,962		160,940		219,572		CHOPS	220,498		204,963		198,313		160,940
Poseidon	Poseidon	265,359		253,341		302,180		266,261		Poseidon	262,800		265,359		251,872		302,180
Odyssey	Odyssey	125,170		114,006		131,771		133,375		Odyssey	100,237		125,170		98,742		131,771
GOPL (2)		8,646		2,631		7,716		4,940
GOPL(3)										GOPL(3)	8,579		8,646		6,777		7,716
Total crude oil offshore pipelines	Total crude oil offshore pipelines	604,138		566,940		602,607		624,148		Total crude oil offshore pipelines	592,114		604,138		555,704		602,607

Natural gas transportation volumes (MMBtus/d)		347,123		329,876		336,456		375,283
Natural gas transportation volumes (MMBtus/day)										Natural gas transportation volumes (MMBtus/day)	384,330		347,123		328,423		336,456

Volumetric Data net to our ownership interest (3):
Volumetric Data net to our ownership interest(4):										Volumetric Data net to our ownership interest(4):
Crude oil pipelines (average barrels/day unless otherwise noted):	Crude oil pipelines (average barrels/day unless otherwise noted):									Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS		204,963		196,962		160,940		219,572
CHOPS(5)										CHOPS(5)	141,119		204,963		126,920		160,940
Poseidon	Poseidon	169,830		162,138		193,395		170,407		Poseidon	168,192		169,830		161,198		193,395
Odyssey	Odyssey	36,299		33,062		38,214		38,679		Odyssey	29,069		36,299		28,635		38,214
GOPL (2)		8,646		2,631		7,716		4,940
GOPL(3)										GOPL(3)	8,579		8,646		6,777		7,716
Total crude oil offshore pipelines	Total crude oil offshore pipelines	419,738		394,793		400,265		433,598		Total crude oil offshore pipelines	346,959		419,738		323,530		400,265

Natural gas transportation volumes (MMBtus/d)		108,695		106,919		105,614		127,695
Natural gas transportation volumes (MMBtus/day)										Natural gas transportation volumes (MMBtus/day)	119,376		108,695		105,625		105,614

(1)Offshore pipeline transportation Segment Margin for the three and six months ended June 30, 2022 includes distributions received from one of our unrestricted subsidiaries, Independence Hub LLC, of $32.0 million associated with the sale of our 80% owned platform asset.

(2)Offshore pipeline transportation Segment Margin includes distributions received from our offshore pipeline joint ventures accounted for under the equity method of accounting in ~~2021~~2022 and ~~2020,~~2021, respectively.

~~(2)~~(3)One of our wholly-owned subsidiaries (GEL Offshore Pipeline, LLC, or “GOPL”) owns our undivided interest in the Eugene Island pipeline system.

(4)Volumes are the product of our effective ownership interest through the year, including changes in ownership interest, multiplied by the relevant throughput over the given year.

~~(3)~~(5)~~One of our wholly-owned subsidiaries (GEL Offshore Pipeline, LLC, or "GOPL") owns our undivided~~On November 17, 2021, we divested a 36% minority interest in our CHOPS pipeline. The volumes for the ~~Eugene Island pipeline system.~~three and six months ended June 30, 2022 represent our 64% net ownership and the volumes presented for the three and six months ended June 30, 2021 represent our 100% ownership during that period.

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Offshore pipeline transportation Segment Margin for the ~~2021~~2022 Quarter increased ~~$8.0~~$35.9 million, or ~~11%~~43%, from the ~~2020~~2021 Quarter primarily ~~due to higher~~as a result of: (i) distributions received from one of our unrestricted subsidiaries, Independence Hub LLC, of

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$32 million for the sale of our 80% owned platform asset; (ii) increased crude oil and natural gas ~~transportation volumes. During~~activity and associated revenues during the ~~2021~~2022 Quarter, ~~we transported higher volumes on our 100% owned SEKCO pipeline~~primarily as a result of ~~increased~~first oil being achieved on April 12, 2022 at the King’s Quay floating production ~~activity from~~system; and (iii) contractual minimum volume commitments (“MVCs”) at King’s Quay and Argos that began in the ~~Buckskin~~2022 Quarter and ~~Lucius fields,~~contributed to our reported Segment Margin.

The King’s Quay floating production system, which ~~are fully~~is supporting the Khaleesi, Mormont and Samurai field developments, is life-of-lease dedicated to ~~SEKCO~~our 100% owned crude oil and natural gas lateral pipelines and further downstream to ~~Poseidon. Additionally, we experienced less downtime~~our 64% owned Poseidon and CHOPS crude oil systems or our 25.67% owned Nautilus natural gas system for ultimate delivery to shore. While the volumes during the ~~2021~~2022 Quarter from King’s Quay were below the contracted MVCs, we were still able to recognize our MVCs in Segment Margin. We expect King’s Quay to ramp up to its design capacity over the remainder of the year as the ~~2020~~operator brings the remaining wells on-line. In addition, we have contractual MVCs that began in the 2022 Quarter ~~was impacted by extended downtime due~~associated with the Argos floating production system (which supports the Mad Dog 2 development), and are included in our reported Segment Margin during the 2022 Quarter. Argos is anticipated to have first oil in the ~~economic environment~~second half of 2022. These increases more than offset the effects from ~~the Covid-19 pandemic and~~our decrease in ownership of CHOPS, as we sold a ~~result of weather interruptions from Tropical Storm Cristobal.~~36% minority interest on November 17, 2021.

Six Months Ended June 30, ~~2021~~2022 Compared with Six Months Ended June 30, ~~2020~~2021

Offshore pipeline transportation Segment Margin for the first six months of ~~2021~~2022 increased ~~$7.0~~$22.5 million, or 4%13%, from the first six months of ~~2020,~~2021 primarily due to: (i) distributions received from one of our unrestricted subsidiaries, Independence Hub LLC, of $32 million for the sale of our 80% owned platform asset, and (ii) increased crude oil and natural gas activity, primarily from first oil achievement at King’s Quay on April 12, 2022, as well as MVCs associated with both King’s Quay and Argos as discussed above. These increases were partially offset by an increased level of downtime during 2022, specifically in the first quarter, that was primarily a result of ~~the increased~~unplanned operational maintenance associated with one of our lateral pipelines that also impacted volumes ~~transported~~ on our ~~100% owned SEKCO~~main pipeline downstream of it, which was remedied in the first quarter of 2022, and incremental producer downtime. Lastly, the 2022 period was impacted, relative to the 2021 period, by our decrease in ownership of CHOPS, as we sold a ~~result of increased production activity from the Buckskin and Lucius fields, which are fully dedicated to SEKCO and further~~36% minority interest on November 17, 2021.

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downstream to Poseidon. This increase in volumes was partially offset by lower volumes during 2021 on our CHOPS pipeline, as it was out of service through February 3, 2021 due to damage at a junction platform that the system goes up and over as a result of the 2020 hurricane season. On February 4, 2021, we placed the CHOPS pipeline back into service upon the installation of a bypass that allows our pipeline to operate around the junction platform. The lower CHOPS pipeline volumes were partially offset by increased distributions from our equity method investments, primarily associated with our 64% owned Poseidon oil pipeline system, as we were able to successfully divert CHOPS volumes to Poseidon during its out of service period.

Sodium Minerals and Sulfur Services Segment

Operating results for our sodium minerals and sulfur services segment were as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
Volumes sold:	Volumes sold:									Volumes sold:
NaHS volumes (Dry short tons "DST")		28,052		21,942		56,854		52,024
NaHS volumes (Dry short tons “DST”)										NaHS volumes (Dry short tons “DST”)	35,633		28,052		67,802		56,854
Soda Ash volumes (short tons sold)	Soda Ash volumes (short tons sold)	772,132		594,810		1,534,952		1,417,057		Soda Ash volumes (short tons sold)	772,141		772,132		1,516,929		1,534,952
NaOH (caustic soda) volumes (DST)	NaOH (caustic soda) volumes (DST)	21,124		20,326		41,386		36,629		NaOH (caustic soda) volumes (DST)	22,073		21,124		42,797		41,386

Revenues (in thousands):	Revenues (in thousands):									Revenues (in thousands):
NaHS revenues, excluding non-cash revenues	NaHS revenues, excluding non-cash revenues	$	30,134	$	23,326	$	60,270	$	56,517	NaHS revenues, excluding non-cash revenues	$	52,184	$	30,134	$	93,812	$	60,270
NaOH (caustic soda) revenues	NaOH (caustic soda) revenues	9,799		8,644		18,206		16,085		NaOH (caustic soda) revenues	16,666		9,799		30,677		18,206
Revenues associated with Alkali Business	Revenues associated with Alkali Business	173,779		141,898		341,103		318,134		Revenues associated with Alkali Business	219,032		173,779		422,691		341,103
Other revenues	Other revenues	893		462		1,823		1,105		Other revenues	2,572		893		4,453		1,823
Total external segment revenues, excluding non-cash revenues(1)	Total external segment revenues, excluding non-cash revenues(1)	$	214,605	$	174,330	$	421,402	$	391,841	Total external segment revenues, excluding non-cash revenues(1)	$	290,454	$	214,605	$	551,633	$	421,402

Segment Margin (in thousands)	Segment Margin (in thousands)	$	38,194	$	24,824	$	81,914	$	61,765	Segment Margin (in thousands)	$	71,701	$	38,194	$	139,076	$	81,914

Average index price for NaOH per DST(2)	Average index price for NaOH per DST(2)	$	755	$	698	$	702	$	673	Average index price for NaOH per DST(2)	$	1,077	$	755	$	1,024	$	702

(1)Totals are for external revenues and costs prior to intercompany elimination upon consolidation.

(2)Source: IHS Chemical.

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Sodium minerals and sulfur services Segment Margin for the ~~2021~~2022 Quarter increased ~~$13.4~~$33.5 million, or ~~54%. This increase is~~88%, from the 2021 Quarter primarily due to higher ~~soda ash volumes and favorable~~ export pricing in our Alkali Business and ~~higher NaHS sales~~increased volumes and pricing in our refinery services ~~business during the 2021 Quarter. During the 2020 Quarter, volume demand in~~business. In our Alkali Business, ~~was significantly impacted by the worldwide economic shutdowns and uncertainty from the Covid-19 pandemic. As economies~~we have continued to ~~open up~~see strong demand improvement and ~~reduce restrictions, we have seen~~growth as a result of the global economic recovery and the continued application of soda ash in everyday end use products and in products such as solar panels and lithium batteries that are expected to play a large role in the anticipated energy transition. This continued demand, ~~recovery, both domestically~~combined with flat or even slightly declining supply of natural soda ash in the near term, has tightened the overall supply and ~~internationally through ANSAC. We continued~~demand balance and created a higher price environment for our tons and increased contribution to ~~produce at a high rate at our Westvaco facility~~Segment Margin during the ~~2021~~2022 Quarter ~~despite a short halt in production for~~from our ~~long-wall move~~Alkali Business. We expect to continue to see this favorable price environment throughout 2022 and ~~certain other planned maintenance activities. Additionally, we saw slightly favorable export pricing in the 2021 Quarter relative~~until there are significant changes to the ~~2020 Quarter~~supply level entering the market. To take advantage of the existing market conditions, we made the decision and ~~sequentially from~~are still on schedule to re-start our original Granger production facility and its roughly 500,000 tons of annual production in the first quarter of 2021, which is evidence that the supply and demand balance is becoming more balanced. These increases were partially offset by lower domestic pricing and lower sales volumes associated with our Granger facility, as it was put2023 in ~~cold standby during the second half~~advance of ~~2020. Our Granger facility is expected to come back online during the second half of 2023 upon~~ the completion of the ~~GOP.~~Granger Optimization Project (“GOP”), which represents an incremental 750,000 tons of annual production, and is expected to have first production in the third quarter of 2023. In our refinery services business, we ~~reported higher~~had an increase in NaHS sales volumes and the corresponding pricing of these sales volumes in the ~~2021~~2022 Quarter due to ~~improved volume~~an increase in demand from our ~~domestic pulp and paper customer base that was negatively impacted~~mining customers, primarily in ~~2020~~South America, as a result of the ~~timing~~continued global economic recovery and the use of ~~spring turnarounds~~NaHS in products, such as copper, that are a key part of the anticipated energy transition. Additionally, during the 2022 Quarter, we were able to leverage our multi-faceted supply and ~~outages due~~terminal sites in our refinery services business to ~~the Covid-19 pandemic.~~capitalize on incremental spot volumes as certain of our competitors experienced supply challenges.

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Six Months Ended June 30, ~~2021~~2022 Compared with Six Months Ended June 30, ~~2020~~2021

Sodium minerals and sulfur services Segment Margin for the first six months of ~~2021~~2022 increased ~~$20.1~~$57.2 million, or ~~33%~~70%, from the first six months of ~~2020. This increase is~~2021 primarily due to higher ~~soda ash volumes and more favorable~~ export pricing in our Alkali ~~Business~~business and ~~higher NaHS sales~~increased volumes and pricing in our refinery services ~~business during 2021. During the 2020 Quarter, volume demand in~~business. In our Alkali Business, ~~was significantly impacted by the worldwide economic shutdowns and uncertainty from the Covid-19 pandemic. As economies~~we have continued to ~~open up~~see strong demand improvement and ~~reduce restrictions, we have seen demand~~growth as a result of the global economic recovery ~~both~~

~~Table~~and the continued application of ~~Contents~~

~~domestically~~soda ash in everyday end use products and ~~internationally through ANSAC,~~in products such as solar panels and continued to produce at a high rate at our Westvaco facility during 2021. Additionally, relative to 2020, we benefited from slightly favorable export pricing in 2021. These increases were partially offset by lower domestic pricing and lower sales volumes associated with our Granger facility, as it was put in cold standby during the second half of 2020. Our Granger facility islithium batteries that are expected to ~~come back online~~play a large role in the anticipated energy transition. This continued demand, combined with flat or even slightly declining supply of natural soda ash in the near term, has tightened the overall supply and demand balance and created a higher price environment for our tons and increased contribution to Segment Margin during ~~the second half of 2023 upon the completion of the GOP.~~2022 from our Alkali Business. In our refinery services business, we ~~reported higher~~had an increase in NaHS sales volumes and the corresponding pricing of these sales volumes in ~~2021 primarily~~2022 due to ~~improved~~an increase in demand from our ~~domestic~~mining and pulp and paper ~~customer base that was negatively impacted in 2020~~customers as a result of the ~~timing~~continued global economic recovery and the use of ~~spring turnarounds and outages due to~~NaHS in products, such as copper, that are a key part of the ~~Covid-19 pandemic. This was partially offset by lower demand from our mining customers, primarily in Peru.~~

anticipated energy transition.

Onshore Facilities and Transportation Segment

Our onshore facilities and transportation segment utilizes an integrated set of pipelines and terminals, ~~as well as~~ trucks ~~railcars,~~ and barges to facilitate the movement of crude oil and refined products on behalf of producers, refiners and other customers. This segment includes crude oil and refined products pipelines, terminals and rail unloading facilities operating primarily within the ~~United States~~U.S. Gulf Coast crude oil market. In addition, we utilize our ~~railcar and~~ trucking ~~fleets~~fleet that ~~support~~supports the purchase and sale of gathered and bulk purchased crude oil, as well as purchased and sold refined products. Through these assets we offer our customers a full suite of services, including the following:

•facilitating the transportation of crude oil from producers to refineries and from owned and third party terminals to refiners via pipelines;

•shipping crude oil and refined products to and from producers and refiners via trucks ~~pipelines,~~ and ~~railcars;~~pipelines;

•unloading railcars at our crude-by-rail terminals;

•storing and blending of crude oil and intermediate and finished refined products;

•purchasing/selling and/or transporting crude oil from the wellhead to markets for ultimate use in refining; and

•purchasing products from refiners, transporting those products to one of our terminals and blending those products to a quality that meets the requirements of our customers and selling those products (primarily fuel oil, asphalt and other heavy refined products) to wholesale markets.

We also may use our terminal facilities to take advantage of contango market conditions ~~to gather~~for crude oil gathering and ~~market crude oil,~~marketing and to capitalize on regional opportunities which arise from time to time for both crude oil and petroleum products. When we purchase and store crude oil during periods of contango, we attempt to limit direct commodity price risk by simultaneously entering into a contract to sell the inventory in a future period, either with a counterparty or in the crude oil futures market.

Despite crude oil being considered a somewhat homogeneous commodity, many refiners are very particular about the quality of crude oil feedstock they process. Many U.S. refineries have distinct configurations and product slates that require crude oil with specific characteristics, such as gravity, sulfur content and metals content. The refineries evaluate the costs to obtain, transport and process their preferred feedstocks. That particularity provides us with opportunities to help the refineries in our areas of operation identify crude oil sources and transport crude oil meeting their requirements. The imbalances and inefficiencies relative to meeting the refiners’ requirements may also provide opportunities for us to utilize our purchasing and logistical skills and assets to meet their demands. The pricing in the majority of our crude oil purchase contracts contains a market price component and a deduction to cover the cost of transportation and to provide us with a margin. Contracts sometimes contain a grade differential which considers the chemical composition of the crude oil and its appeal to different customers. Typically, the pricing in a contract to sell crude oil will consist of the market price components and the grade differentials. The margin on individual transactions is then dependent on our ability to manage our transportation costs and to capitalize on grade differentials.

In our refined products marketing operations, we supply primarily fuel oil, asphalt and other heavy refined products to wholesale markets and some end-users such as paper mills and utilities. We also provide a service to refineries by purchasing “heavier” petroleum products that are the residual fuels from gasoline production, transporting them to one of our terminals and blending them to a quality that meets the requirements of our customers.

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Operating results from our onshore facilities and transportation segment were as follows:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
Gathering, marketing, and logistics revenue	Gathering, marketing, and logistics revenue	$	136,148	$	59,830	$	314,710	$	195,137	Gathering, marketing, and logistics revenue	$	234,777	$	136,148	$	448,421	$	314,710
Crude oil and CO2 pipeline tariffs and revenues		8,902		14,145		18,877		34,006
Crude oil pipeline tariffs and revenues										Crude oil pipeline tariffs and revenues	8,025		8,902		15,359		18,877
Distributions from unrestricted subsidiaries not included in income (1)	Distributions from unrestricted subsidiaries not included in income (1)	17,500		2,294		35,000		4,532		Distributions from unrestricted subsidiaries not included in income(1)	—		17,500		—		35,000
Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions	Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions	(124,383)		(42,783)		(286,367)		(154,277)		Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions	(217,711)		(124,383)		(417,716)		(286,367)
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses	Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses	(15,431)		(17,877)		(30,697)		(36,370)		Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses	(16,573)		(15,431)		(32,342)		(30,697)
Other	Other	(368)		5,606		(8,156)		6,286		Other	2,500		(368)		4,332		(8,156)
Segment Margin	Segment Margin	$	22,368	$	21,215	$	43,367	$	49,314	Segment Margin	$	11,018	$	22,368	$	18,054	$	43,367

Volumetric Data (average barrels per day unless otherwise noted):	Volumetric Data (average barrels per day unless otherwise noted):									Volumetric Data (average barrels per day unless otherwise noted):
Onshore crude oil pipelines:	Onshore crude oil pipelines:									Onshore crude oil pipelines:
Texas(2)	Texas(2)	84,551		62,261		58,800		73,380		Texas(2)	93,739		84,551		81,604		58,800
Jay	Jay	7,933		5,067		8,356		7,540		Jay	6,663		7,933		6,788		8,356
Mississippi	Mississippi	5,327		4,883		5,213		5,646		Mississippi	6,233		5,327		5,989		5,213
Louisiana ~~(2)~~(3)	Louisiana ~~(2)~~(3)	46,319		33,032		54,821		83,635		Louisiana ~~(2)~~(3)	51,422		46,319		41,457		54,821

Onshore crude oil pipelines total	Onshore crude oil pipelines total	144,130		105,243		127,190		170,201		Onshore crude oil pipelines total	158,057		144,130		135,838		127,190

CO2 pipeline (average Mcf/day):
Free State (3)		—		94,282		—		114,558

Crude oil and petroleum products sales:	Crude oil and petroleum products sales:									Crude oil and petroleum products sales:
Total crude oil and petroleum products sales	Total crude oil and petroleum products sales	20,653		21,874		26,028		23,996		Total crude oil and petroleum products sales	22,060		20,653		22,968		26,028
Rail unload volumes	Rail unload volumes	3,556		4,150		21,803		49,095		Rail unload volumes	25,680		3,556		14,156		21,803

(1)The three and six months ended June 30, 2021 ~~include~~includes total cash payments received ~~from our previously owned NEJD pipeline~~ of $17.5 million and $35.0 million, respectively, not included in income ~~respectively. The three~~from the NEJD pipeline. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our senior secured credit agreement.

(2)Our Texas pipeline and infrastructure is a destination point for many pipeline systems in the Gulf of Mexico, including the CHOPS pipeline. Volumes during the six months ended June 30, 2021 were impacted as a result of the CHOPS pipeline being out of service from August 26, 2020 ~~includes cash payments received from the NEJD pipeline of $5.2 million and $10.3 million, respectively, of which $2.3 million and $4.5 million, respectively, were not included in income.~~to February 4, 2021.

~~(2)~~ (3)Total daily volume for the three and six months ended June 30, ~~2021~~2022 includes ~~39,875~~29,469 and ~~32,397~~29,097 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines. Total daily volume for the three and six months ended June 30, ~~2020~~2021 includes ~~28,851~~39,875 and ~~36,586~~32,397 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines.

~~(3) The assets owned by Genesis Free State Pipeline, LLC were sold on October~~Three Months Ended June 30, ~~2020.~~

2022 Compared with Three Months Ended June 30, 2021 ~~Compared with~~ ~~Three Months Ended~~ ~~June 30, 2020~~

Onshore facilities and transportation Segment Margin for the 2022 Quarter decreased $11.4, or 51%, from the 2021 ~~Quarter increased $1.2 million, or 5%.~~Quarter. This ~~increase~~decrease is primarily due to ~~higher cash receipts received during~~ the 2021 Quarter ~~from Denbury~~including cash receipts of ~~approximately $12.3~~$17.5 million associated with our previously owned NEJD pipeline. The last principal payment associated with our previously owned NEJD pipeline aswas received in the fourth quarter of 2021. This decrease was partially offset by higher rail unload and pipeline volumes, primarily associated with our assets in the Baton Rouge corridor. Our increase in rail volumes was a result of our ~~agreement reached during~~main customer sourcing volumes to replace international volumes that were impacted by certain geopolitical events and we expect these volumes to continue into the ~~fourth~~third quarter of ~~2020. This increase was partially offset by: (i) lower contracted minimum volume commitments with~~2022. Additionally, we had higher volumes on our ~~main customer associated with our Baton Rouge corridor assets (including rail, terminal and~~Texas pipeline, ~~volumes), as these commitments stepped down beginning in 2021, and the use~~which is a destination point for various grades of built up prepaid transportation credits during the 2021 Quarter by our main customer; and (ii) the divestiture of our Free State pipeline during the fourth quarter of 2020, which contributed positively to Segment Margincrude oil produced in the ~~2020 Quarter.~~Gulf of Mexico including those transported on our 64% owned CHOPS pipeline.

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Six Months Ended June 30, ~~2021~~2022 Compared with Six Months Ended June 30, ~~2020~~2021

Onshore facilities and transportation Segment Margin for the first six months of ~~2021~~2022 decreased ~~$5.9~~$25.3 million, or ~~12%, from~~58% primarily due to the first six months of 2020. This decrease was primarily due to lower rail unload and crude oil pipeline volumes associated with our Baton Rouge corridor assets, in addition to our customer utilizing certain of its prepaid transportation credits that accumulated during 2020, and the divestiture of our Free State pipeline during the fourth quarter of 2020, which contributed

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~~positively to Segment Margin during the six months ended June 30, 2020. These decreases were partially offset by higher~~2021 including cash receipts ~~received during the six months ended June 30, 2021 from Denbury~~ of approximately ~~$24.7~~$35 million associated with our previously owned NEJD pipeline. This decrease was partially offset by higher contributions to Segment Margin from our pipeline, ~~as a result~~rail, and terminal assets in the Baton Rouge corridor. While the volumes were lower during 2022 compared to 2021, our main customer utilized prepaid transportation credits during 2021, which were fully utilized by the end of ~~our agreement reached during the fourth quarter of 2020.~~

2021.

Marine Transportation Segment

Within our marine transportation segment, we own a fleet of 91 barges (82 inland and 9 offshore) with a combined transportation capacity of 3.2 million barrels, 42 push/tow boats (33 inland and 9 offshore), and a 330,000 barrel ocean going tanker, the M/T American Phoenix. Operating results for our marine transportation segment were as follows:


		Three Months Ended June 30,						Six Months Ended June 30,							Three Months Ended June 30,						Six Months Ended June 30,
		2021			2020			2021			2020				2022			2021			2022			2021
Revenues (in thousands):	Revenues (in thousands):													Revenues (in thousands):
Inland freight revenues	Inland freight revenues	$	18,231		$	25,805		$	35,746		$	53,377		Inland freight revenues	$	26,196		$	18,231		$	47,232		$	35,746
Offshore freight revenues	Offshore freight revenues	16,504			22,268			31,030			43,359			Offshore freight revenues	23,953			16,504			42,891			31,030
Other rebill revenues (1)	Other rebill revenues (1)	12,891			8,647			21,181			22,330			Other rebill revenues(1)	26,171			12,891			41,971			21,181
Total segment revenues	Total segment revenues	$	47,626		$	56,720		$	87,957		$	119,066		Total segment revenues	$	76,320		$	47,626		$	132,094		$	87,957

Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)	Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)	$	39,158		$	38,582		$	72,380		$	81,926		Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)	$	58,747		$	39,158		$	102,384		$	72,380

Segment Margin (in thousands)	Segment Margin (in thousands)	$	8,468		$	18,138		$	15,577		$	37,140		Segment Margin (in thousands)	$	17,573		$	8,468		$	29,710		$	15,577

Fleet Utilization: (2)	Fleet Utilization: (2)													Fleet Utilization:(2)
Inland Barge Utilization	Inland Barge Utilization	81.2		%	87.6		%	76.6		%	90.5		%	Inland Barge Utilization	99.6		%	81.2		%	95.0		%	76.6		%
Offshore Barge Utilization	Offshore Barge Utilization	96.8		%	96.8		%	96.3		%	98.1		%	Offshore Barge Utilization	97.9		%	96.8		%	97.3		%	96.3		%

(1)Under certain of our marine contracts, we ~~"rebill"~~“rebill” our customers for a portion of our operating costs.

(2)Utilization rates are based on a ~~365 day~~365-day year, as adjusted for planned downtime and dry-docking.

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Marine transportation Segment Margin for the ~~2021~~2022 Quarter ~~decreased $9.7~~increased $9.1 million, or ~~53%~~108%, from the ~~2020~~2021 Quarter. This ~~decrease~~increase is primarily attributable to ~~lower~~higher utilization and day rates in our inland business and higher day rates in our offshore business, including the M/T American Phoenix, during the 2022 Quarter. We have continued to see an increase in demand and utilization of our vessels as refinery utilization has increased and the supply of like maritime equipment is tight due to net equipment retirements. While we have continued to see increases in our day rates from both the 2021 Quarter and ~~lower rates in our offshore barge operation, including our M/T American Phoenix tanker. During~~sequentially from the ~~2021 Quarter,~~first quarter of 2022, we began to see sequential improvement in the offshore barge spot market pricing, but we expect to see continued pressure on our utilization, and to an extent, the spot rates in our inland business as Midwest and Gulf Coast refineries have continued to run at lower utilization rates to better align with overall demand as a result of Covid-19 and the current operating environment. We have continued to enter into short term contracts (less than a year) in ~~both~~ the inland and offshore markets, including the M/T American Phoenix, because we believe the day rates currently being offered by the market have yet to fully recover from their cyclical lows. Additionally, during July 2022, the M/T American Phoenix went into her planned mandatory 30-45 day regulatory dry-dock and we have contracted her for four months beginning in September 2022 with an investment grade customer at a rate of meaningfully higher than the 2022 Quarter rate.

Six Months Ended June 30, 2022 Compared with Six Months Ended June 30, 2021

Marine transportation Segment Margin for the first six months of 2022 increased $14.1 million, or 91%, from the first six months of 2021. This increase is primarily attributable to higher utilization and day rates in our inland business and higher day rates in our offshore business, including the M/T American Phoenix, during the 2022 Quarter. While we have continued to see increases in our day rates from 2021 and throughout 2022, we have continued to enter into short term contracts (less than a year) in the inland and offshore markets, including the M/T American Phoenix, because we believe the day rates currently being offered by the market have yet to fully recover from their cyclical lows.

Other Costs, Interest and Income Taxes

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~~Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020~~

Marine transportation Segment Margin for the first six months of 2021 decreased $21.6 million, or 58%, from the first six months of 2020. This decrease is primarily attributable to lower utilization and day rates in our inland business during the 2021 Quarter and lower rates in our offshore barge operation, including our M/T American Phoenix tanker. We expect to see continued pressure on our utilization, and to an extent, the spot rates in our inland business as Midwest and Gulf Coast refineries have continued to run at lower utilization rates to better align with overall demand as a result of Covid-19 and the current operating environment. We have continued to enter into short term contracts (less than a year) in both the inland and offshore markets because we believe the day rates currently being offered by the market have yet to fully recover from their cyclical lows. We also re-contracted our M/T American Phoenix tanker beginning in the 2021 Quarter for one year, but at a lower rate than our previous long-term contract that ended during the second half of 2020.

~~Other Costs, Interest, and Income Taxes~~

General and administrative expenses


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
General and administrative expenses not separately identified below:	General and administrative expenses not separately identified below:									General and administrative expenses not separately identified below:
Corporate	Corporate	$	10,368	$	23,364	$	19,789	$	34,157	Corporate	$	13,004	$	10,368	$	24,956	$	19,789
Segment	Segment	1,036		1,073		2,087		2,138		Segment	895		1,036		1,854		2,087
Long-term incentive compensation expense	Long-term incentive compensation expense	882		955		1,962		(1,530)		Long-term incentive compensation expense	1,436		882		3,035		1,962
Third party costs related to business development activities and growth projects	Third party costs related to business development activities and growth projects	621		21		735		21		Third party costs related to business development activities and growth projects	5,330		621		5,942		735
Total general and administrative expenses	Total general and administrative expenses	$	12,907	$	25,413	$	24,573	$	34,786	Total general and administrative expenses	$	20,665	$	12,907	$	35,787	$	24,573

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Total general and administrative expenses for the ~~2021~~2022 Quarter ~~decreased~~increased by ~~$12.5 million. This decrease is~~$7.8 million primarily due to ~~the 2020 Quarter including a one-time charge of approximately $13 million~~higher third party costs related to ~~certain severance~~business development activities and ~~restructuring expenses.~~growth projects as a result of the issuance of our Alkali senior secured notes and related sale of the ORRI Interests. We also incurred third party costs in the 2022 Quarter associated with the divestiture of our previously owned Independence Hub platform. Additionally, we had increased corporate general and administrative expenses during the 2022 Quarter.

Six Months Ended June 30, ~~2021~~2022 Compared with Six Months Ended June 30, ~~2020~~2021

Total general and administrative expenses for the first six months of ~~2021 decreased~~2022 increased by ~~$10.2~~$11.2 million primarily due to ~~the 2020 Quarter including a one-time charge of approximately $13 million~~higher third party costs related to ~~certain severance~~business development activities and ~~restructuring expenses. This was partially offset by higher long-term incentive compensation expense~~growth projects as a result of ~~changes~~the issuance of our Alkali senior secured notes and related sale of the ORRI Interests. We also incurred third party costs in ~~assumptions used to value~~the 2022 Quarter associated with the divestiture of our ~~outstanding awards between~~previously owned Independence Hub platform. Additionally, we had increased corporate general and administrative expenses during the ~~two periods.~~first six months of 2022.

Depreciation, depletion and amortization expense

Three Months Ended
June 30, Six Months Ended
June 30,
2021 2020 2021 2020
(in thousands) (in thousands)
Depreciation and depletion expense $ 64,852 $ 75,930 $ 128,466 $ 146,135
Amortization expense 2,689 4,190 5,361 8,342
Total depreciation, depletion and amortization expense $ 67,541 $ 80,120 $ 133,827 $ 154,477


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Depreciation and depletion expense	$	70,947	$	64,852	$	137,717	$	128,466
Amortization expense	2,726		2,689		5,462		5,361
Total depreciation, depletion and amortization expense	$	73,673	$	67,541	$	143,179	$	133,827

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Total depreciation, depletion and amortization expense for the ~~2021~~2022 Quarter ~~decreased~~increased by ~~$12.6~~$6.1 million. This ~~decrease~~increase is primarily attributable to an overall increase in our depreciable asset base due to ~~lower depreciation expense associated with~~ our ~~rail logistics~~continued growth and maintenance capital expenditures and placing new assets in the 2021 Quarter as they were impaired during the second quarter of 2020. Additionally, our contract intangible associated with the M/T American Phoenix became fully amortized on September 30, 2020, which resulted in lower amortization expense ininto service subsequent to the 2021 Quarter.

Six Months Ended June 30, 2022 Compared with Six Months Ended June 30, 2021

Total depreciation, depletion and amortization expense for the first six months of 2022 increased by $9.4 million. This increase is primarily attributable to an overall increase in our depreciable asset base due to our continued growth and maintenance capital expenditures and placing new assets into service subsequent to the first six months of 2021.

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~~Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020~~

Total depreciation, depletion, and amortization expense for the first six months of 2021 decreased by $20.7 million due to lower depreciation expense associated with our rail logistics assets in 2021 as they were impaired during the second quarter of 2020. Additionally, our contract intangible associated with the M/T American Phoenix became fully amortized on September 30, 2020, which resulted in lower amortization expense in the 2021 Quarter.

~~Impairment Expense~~

During the three and six months ended June 30, 2020, we recorded impairment expenses of $277.5 million associated with the rail logistics assets included within our onshore facilities and transportation segment. We had no impairment expense during 2021.

Interest expense, net


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2021		2020		2021		2020			2022		2021		2022		2021
		(in thousands)				(in thousands)					(in thousands)				(in thousands)
Interest expense, senior secured credit facility (including commitment fees)	Interest expense, senior secured credit facility (including commitment fees)	$	5,812	$	9,664	$	13,243	$	20,409	Interest expense, senior secured credit facility (including commitment fees)	$	1,680	$	5,812	$	3,627	$	13,243
Interest expense, Alkali senior secured notes										Interest expense, Alkali senior secured notes	3,105		—		3,105		—
Interest expense, senior unsecured notes	Interest expense, senior unsecured notes	51,859		40,202		100,194		82,560		Interest expense, senior unsecured notes	52,980		51,859		106,059		100,194
Amortization of debt issuance costs and premium		2,255		2,200		4,970		4,591
Amortization of debt issuance costs, premium and discount										Amortization of debt issuance costs, premium and discount	2,116		2,255		4,151		4,970
Capitalized interest	Capitalized interest	(757)		(448)		(1,409)		(977)		Capitalized interest	(3,922)		(757)		(5,879)		(1,409)
Net interest expense		$	59,169	$	51,618	$	116,998	$	106,583
Interest expense, net										Interest expense, net	$	55,959	$	59,169	$	111,063	$	116,998

Three Months Ended June 30, ~~2021~~2022 Compared with Three Months Ended June 30, ~~2020~~2021

Net interest expense for the ~~2021~~2022 Quarter ~~increased $7.6~~decreased by $3.2 million primarily due to lower interest on our senior secured credit facility and higher capitalized interest. The decrease in interest expense associated with our senior secured credit facility is primarily due to a lower outstanding balance throughout the 2022 Quarter as a result of: (i) the proceeds we received from the additional issuance of $250 million in aggregate principal of our 2027 Notes in April 2021; (ii) the proceeds from the sale of a noncontrolling interest in our CHOPS pipeline in November 2021; and (iii) the excess proceeds we received from the issuance of our Alkali senior secured notes in May 2022, all of which were used to pay down the outstanding balance under our senior secured credit facility. Additionally, we had higher capitalized interest during the 2022 Quarter as a result of our increased capital expenditures associated with the GOP and our offshore growth capital construction projects, both of which are being funded internally.

This decrease was offset by increased interest expense associated with our Alkali senior ~~unsecured notes. On December 17, 2020, we~~secured notes due 2042 that were issued ~~our $750 million 2027 Notes that accrue~~during May 2022, which bear interest at ~~8.00% and we purchased and extinguished the remaining principal balance of our 6.00% 2023 Notes on January 19, 2021. On April 22,~~5.875%.

Six Months Ended June 30, 2022 Compared with Six Months Ended June 30, 2021 we issued an additional $250 million in aggregate principal amount of notes under the same terms as our 2027 Notes. The excess proceeds received from the issuance of our 2027 Notes were used to repay borrowings on our revolving credit facility.

~~The increase in~~Net interest expense ~~on our senior unsecured notes was partially offset~~for the first six months of 2022 decreased by $5.9 million primarily due to lower interest ~~expense~~ on our senior secured credit facility. The decrease in interest expense onassociated with our senior secured credit facility ~~was~~is primarily due to a lower outstanding balance throughout the 2022 Quarter as a result of: (i) the proceeds we received from the additional issuance of $250 million in aggregate principal of our 2027 Notes in April 2021; (ii) the proceeds from the sale of a noncontrolling interest in our CHOPS pipeline in November 2021; and (iii) the excess proceeds we received from the issuance of our Alkali senior secured notes in May 2022, all of which were used to pay down the outstanding balance under our senior secured credit facility. Additionally, we had higher capitalized interest during the ~~2021 Quarter.~~2022 Quarter as a result of our increased capital expenditures associated with the GOP and our offshore growth capital construction projects, both of which are being funded internally.

~~Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020~~

~~Net interest expense for the first six months of 2021 increased~~This decrease was offset by ~~$10.4 million primarily due to~~ increased interest expense associated with our senior unsecured ~~notes. On January 16, 2020, we issued our $750 million 2028 Notes that accrue interest at 7.75% and we purchased and extinguished our $750 million 2022~~ notes ~~that accrued interest at 6.75% during 2020. On December 17, 2020, we issued our $750 million 2027 Notes that accrue interest at 8.00% and we purchased and extinguished the remaining principal balance~~as a result of our ~~6.00% 2023 Notes on January 19, 2021. On April 22, 2021, we issued an~~ additional issuance of $250 million in aggregate principal ~~amount of notes under the same terms as our 2027 Notes. The excess proceeds received from the issuance~~ of our 2027 Notes ~~were used to repay borrowings on~~in April 2021, which bears interest at 8% and issuance of our ~~revolving credit facility.~~

~~The increase in interest expenses on our senior unsecured notes was partially offset by lower interest expense on our~~Alkali senior secured ~~credit facility. The decrease in~~notes due 2042 on May 17, 2022, which bear interest ~~expense on our senior secured credit facility was primarily due to a lower outstanding balance during 2021.~~at 5.875%.

Income tax expense

A portion of our operations are owned by wholly-owned corporate subsidiaries that are taxable as corporations. As a result, a substantial portion of the income tax expense we record relates to the operations of those corporations, and will vary from period to period as a percentage of our income before taxes based on the percentage of our income or loss that is derived from those corporations. The balance of the income tax expense we record relates to state taxes imposed on our operations that are treated as income taxes under generally accepted accounting principles and foreign income taxes.

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Liquidity and Capital Resources

General

On April 8, 2021, we entered into our ~~new~~ credit agreement, ~~to replace our existing agreement. Our new credit agreement provides~~which initially provided for a $950 million senior secured credit facility, comprised of our Revolving Loan ~~facility~~ with a borrowing capacity of $650 million and our Term Loan ~~facility~~ with a borrowing capacity of $300 million, with the ability to increase the aggregate size of the ~~revolving loan facility~~Revolving Loan by an additional $200 million subject to lender consent and certain other customary conditions. ~~The new~~Our Term Loan was paid off in full on November 17, 2021 with a portion of the gross proceeds of $418 million received from the sale of a 36% minority interest in CHOPS. Our credit agreement matures on March 15, 2024, subject to extension at our request for one additional year on up to two occasions and subject to certain conditions. Under our new credit agreement, the permitted maximum consolidated leverage ratio is 5.85x through June 30, 2021, 5.75x through March 31, 2022, and then 5.50x thereafter. The permitted maximum consolidated senior secured leverage ratio is 2.50x, and the minimum interest coverage ratio is 2.50x for the full term of the agreement.

On December 17, 2020, we issued $750 million 2027 Notes that accrue interest at 8.00%. We used the net proceeds to repay a portion of our 6.00% 2023 Notes that were validly tendered and we redeemed the remaining principal balance of $80.9 million on our 6.00% 2023 Notes on January 19, 2021. The excess proceeds received from this offering were used to repay borrowings on our revolving credit facility. Furthermore, on April 22, 2021 we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The additional $250 million of notes have identical terms as (other than with respect to issue price) and constitute part of the same series ofas our 2027 ~~Notes. The $250 million of~~Notes and the ~~2027 Notes were issued at a premium of 103.75%, plus accrued interest from December 17, 2020. The~~ net proceeds from this additional offering were used for general partnership purposes, including repaying a portion of the revolving borrowings outstanding under our Revolving Loan.

On May 17, 2022, Genesis Energy, L.P., through its newly created indirect unrestricted subsidiary, GA ORRI, issued $425 million principal amount of our 5.875% Alkali senior secured notes due 2042 to ~~pay down~~certain institutional investors, secured by GA ORRI’s fifty-year limited term overriding royalty interest in substantially all of the Company’s Alkali Business trona mineral leases. The issuance generated net proceeds of $408 million, net of the issuance discount of $17 million. We make quarterly interest payments on our Alkali senior secured notes until March 2024, at which time we begin making principal payments through the maturity date. We used a portion of net proceeds from the issuance to fully redeem the outstanding Alkali Holdings preferred units and utilized the remainder to repay a portion of the outstanding borrowings onunder our Revolving Loan. The redemption of our Alkali Holdings preferred units, which carried an implied interest rate of 12-13%, and the issuance of our Alkali senior secured notes with a coupon rate of 5.875%, has allowed us to simplify and our capital structure and lower our cost of capital, provide us additional flexibility under our Revolving Loan, and remove any risk of refinancing our Alkali Holdings preferred units that were initially due in 2026.

The successful completion of our ~~new~~ credit agreement (including its extended maturity and leverage flexibility) ~~and~~, the refinancing of our previously held 2023 Notes and the sale of a minority interest in CHOPS has resulted in no scheduled maturities of long-term debt until 2024 ~~other than the minimal quarterly payments due under the associated term loan facility each quarter beginning at the end~~and has provided us a significant amount of ~~2021 (which will be funded by the~~ available borrowing capacity under our ~~revolving loan facility).~~

~~As of June 30, 2021, our balance sheet and liquidity position remained strong, which included $530.5 million of remaining borrowing capacity,~~Revolving Loan, subject to compliance with the covenants in our credit agreement, to, amongst other things, utilize for the remaining growth capital expenditures associated with the Granger expansion and our offshore growth projects discussed in further detail below. We also received $40 million, or $32 million net to our ownership interests, for the sale of our 80% owned Independence Hub platform which allowed us to further increase our borrowing capacity as we move forward into the second half of 2022 and beyond. The available borrowing capacity under our ~~new $950 million senior secured credit facility.~~ Revolving Loan at June 30, 2022 is $610.9 million.

We anticipate that our future internally-generated funds and the funds available under our ~~new~~ credit agreement will allow us to meet our ordinary course capital needs. Our primary sources of liquidity have been cash flows from operations, borrowing availability under our ~~prior~~senior secured credit facility, proceeds from the sale of non-core assets, the creation of strategic arrangements to share capital costs through joint ventures or strategic alliances and the proceeds from issuances of equity (common and preferred) and senior unsecured or secured notes.

Our primary cash requirements consist of:

•working capital, primarily inventories ~~payables~~ and ~~accrued liabilities;~~trade receivables and payables;

•routine operating expenses;

•capital growth (as discussed in more detail below) and maintenance projects;

•acquisitions of assets or businesses;

•interest payments related to ~~servicing and reducing~~ outstanding debt;

•asset retirement obligations; and

•quarterly cash distributions to our preferred and common unitholders.

Capital Resources

Our ability to satisfy future capital needs will depend on our ability to raise substantial amounts of additional capital from time to time, — including through equity and debt offerings (public and private), borrowings under our senior secured credit facility and other financing ~~transactions—~~transactions, and to implement our growth strategy successfully. No assurance can be made that we will be able to raise necessary funds on satisfactory ~~terms or implement our growth strategy successfully.~~terms.

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At June 30, ~~2021,~~2022, our long-term debt totaled approximately ~~$3,343.2 million, which is a reduction~~$3.3 billion, consisting of ~~$50.6 million sequentially from December 31, 2020, and consisted of $415.7~~$34.6 million outstanding under our senior secured credit facility ~~net~~ (including ~~$19.6~~$14.3 million borrowed under the inventory sublimit tranche) ~~and $2,927.5 million~~, $2.9 billion of senior unsecured notes, ~~net.~~net and $402.2 million of Alkali senior secured notes, net, which are secured by the ORRI Interests. Our senior unsecured notes, net balance is comprised of ~~$338.6~~$339.5 million carrying amount due on June ~~15,~~ 2024, ~~$529.8~~$531.0 million carrying amount due October 2025, ~~$356.0~~$341.4 million carrying amount due May 2026, ~~$992.6~~$994.2 million carrying value due January ~~15,~~ 2027 and ~~$710.5~~$682.4 million carrying amount due February 1, 2028. We remain focused on continuing to reduce our leverage.

On September 23, 2019, we announced the GOP. We entered into agreements with ~~GSO~~BXC for the purchase of up to approximately $350 million of Alkali Holdings preferred ~~units of Alkali Holdings.~~units. The proceeds received from ~~GSO will~~BXC to date have been utilized to fund ~~up to 100%~~a portion of the anticipated cost of the GOP. On April 14, 2020, we entered into an amendment to our agreements with GSO to, among other things, extend the construction timeline of the GOP by one year. The extended completion date of the project is anticipated in the second half of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to

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GSO, which was accounted for as issuance costs. Additionally, the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. The Alkali Holdings preferred unitholders receive PIK distributions in lieu of cash distributions during the new anticipated construction period. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year. On May 17, 2022, utilizing a portion of the proceeds we received from the issuance of our Alkali senior secured notes, we fully redeemed the 251,750 outstanding Alkali Holdings preferred units at a Base Preferred Return Amount of $288.6 million. As of June 30, 2022, there were no Alkali Holdings preferred units outstanding and we plan to fund the remaining capital expenditures associated with the GOP internally.

Shelf Registration Statement

We have the ability to issue additional equity and debt securities in the future to assist us in meeting our future liquidity requirements, particularly those related to opportunistically acquiring assets and businesses and constructing new facilities and refinancing outstanding debt.

We have a universal shelf registration statement (our ~~"2021 Shelf"~~“2021 Shelf”) on file with the SEC which we filed on April 19, 2021 to replace our existing universal shelf registration statement that expired on April 20, 2021. Our 2021 Shelf allows us to issue an unlimited amount of equity and debt securities in connection with certain types of public offerings. However, the receptiveness of the capital markets to an offering of equity and/or debt securities cannot be assured and may be negatively impacted by, among other things, our long-term business prospects and other factors beyond our control, including market conditions. Our 2021 Shelf is set to expire in April 2024.

Cash Flows from Operations

We generally utilize the cash flows we generate from our operations to fund our distributions and working capital needs. Excess funds that are generated are used to repay borrowings under our senior secured credit facility and/or to fund a portion of our capital expenditures and asset retirement obligations (if any). Our operating cash flows can be impacted by changes in items of working capital, primarily variances in the carrying amount of inventory and the timing of payment of accounts payable and accrued liabilities related to capital ~~expenditures.~~expenditures and interest charges, and the timing of accounts receivable collections from our customers.

We typically sell our purchased crude oil in the same month in which we acquire it, so we do not need to rely on borrowings under our senior secured credit facility to pay for such crude oil purchases, other than inventory. During such periods, our accounts receivable and accounts payable generally move in tandem as we make payments and receive payments for the purchase and sale of crude oil.

In our petroleum products onshore facilities and transportation activities, we purchase products and typically either move those products to one of our storage facilities for further blending or sell those products within days of our purchase. The cash requirements for these activities can result in short term increases and decreases in our borrowings under our senior secured credit facility.

In our Alkali Business, we typically extract trona from our mining facilities, process it into soda ash and other alkali products, and deliver and sell the ~~alkali~~ products to our customers all within a relatively short time frame. If we do experience any differences in timing of extraction, processing and sales of our trona or alkali, ~~products,~~or delays in collections from our sales to customers, it could impact the cash requirements for these activities in the short term.

The storage of our inventory of crude oil, petroleum products and ~~petroleum~~alkali products can have a material impact on our cash flows from operating activities. In the month we pay for the stored crude oil or petroleum products (or pay for extraction and processing activities in the case of alkali products), we borrow under our senior secured credit facility (or use cash on hand) to pay for the crude oil or petroleum products (or extraction/processing of alkali products), utilizing a portion of our operating cash flows. Conversely, cash flow from operating activities increases during the period in which we collect the cash from the sale of the stored crude oil, petroleum products or ~~petroleum~~alkali products. Additionally, we may be required to deposit margin funds with the NYMEX when commodity prices increase as the value of the derivatives utilized to hedge the price risk in our inventory fluctuates. These deposits also impact our operating cash flows as we borrow under our senior secured credit facility or use cash on hand to fund the deposits.

See Note 14 in our Unaudited Condensed Consolidated Financial Statements for information regarding changes in components of operating assets and liabilities for the ~~2021~~2022 Quarter and ~~2020~~2021 Quarter.

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Net cash flows provided by our operating activities for the six months ended June 30, ~~2021~~2022 were ~~$188.2~~$158.3 million compared to ~~$152.2~~$188.2 million for the six months ended June 30, ~~2020. This increase~~2021. The decrease in cash flow from operating activities is primarily attributable to ~~positive~~ changes in working capital ~~during 2021 and transactions costs incurred during 2020 associated~~between the two periods with the ~~tender~~primary difference related to higher interest payments and ~~redemption~~changes in our inventory positions during 2022 compared to 2021. See Note 14 in our Unaudited Condensed Consolidated Financial Statements for information regarding the timing of our ~~previously held~~interest payments. These changes were partially offset by an increase in our operations and reported Segment Margin during the 2022 ~~Notes.~~Quarter.

Capital Expenditures and Distributions ~~and Certain Cash Requirements~~Paid to Our Unitholders

We use cash primarily for our operating expenses, working capital needs, debt service, acquisition activities, ~~organic~~internal growth projects, maintenance capital expenditures and distributions we pay to our preferred and common unitholders. We finance maintenance capital expenditures and smaller ~~organic~~internal growth projects and distributions primarily with cash generated by our operations. We have historically funded material growth capital projects (including acquisitions and ~~organic~~internal growth projects) with borrowings under our senior secured credit facility, equity issuances ~~and/or issuances~~(common and preferred units), the issuance of senior unsecured ~~notes. We currently~~

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~~plan~~strategic arrangements to ~~allocate a substantial portion of our excess cash flow to reduce the balance outstanding under our revolving credit facility and to opportunistically repurchase our outstanding senior unsecured notes.~~share capital costs through joint ventures or strategic alliances.

Capital Expenditures for Fixed and Intangible Assets and Equity Investees

~~A summary of~~The following table summarizes our expenditures for fixed and intangible assets ~~business~~ and ~~other asset acquisitions for 2021 and 2020 are as follows~~:equity investees in the periods indicated:


		Six Months Ended June 30,					Six Months Ended June 30,
		2021		2020			2022		2021
		(in thousands)					(in thousands)
Capital expenditures for fixed and intangible assets:	Capital expenditures for fixed and intangible assets:					Capital expenditures for fixed and intangible assets:
Maintenance capital expenditures:	Maintenance capital expenditures:					Maintenance capital expenditures:
Offshore pipeline transportation assets	Offshore pipeline transportation assets	$	7,371	$	2,097	Offshore pipeline transportation assets	$	3,776	$	7,371
Sodium minerals and sulfur services assets	Sodium minerals and sulfur services assets	16,032		12,051		Sodium minerals and sulfur services assets	25,176		16,032
Marine transportation assets	Marine transportation assets	22,871		17,725		Marine transportation assets	14,129		22,871
Onshore facilities and transportation assets	Onshore facilities and transportation assets	3,453		1,618		Onshore facilities and transportation assets	867		3,453
Information technology systems		190		99
Information technology systems and corporate assets						Information technology systems and corporate assets	2,244		190
Total maintenance capital expenditures	Total maintenance capital expenditures	49,917		33,590		Total maintenance capital expenditures	46,192		49,917
Growth capital expenditures:	Growth capital expenditures:					Growth capital expenditures:
Offshore pipeline transportation assets	Offshore pipeline transportation assets	23,578		913		Offshore pipeline transportation assets	74,708		23,578
Sodium minerals and sulfur services assets	Sodium minerals and sulfur services assets	74,566		36,386		Sodium minerals and sulfur services assets	40,070		74,566
Marine transportation assets	Marine transportation assets	—		—		Marine transportation assets	—		—
Onshore facilities and transportation assets	Onshore facilities and transportation assets	133		368		Onshore facilities and transportation assets	—		133
Information technology systems		4,211		2,515
Information technology systems and corporate assets						Information technology systems and corporate assets	4,433		4,211
Total growth capital expenditures	Total growth capital expenditures	102,488		40,182		Total growth capital expenditures	119,211		102,488
Total capital expenditures for fixed and intangible assets	Total capital expenditures for fixed and intangible assets	$	152,405	$	73,772	Total capital expenditures for fixed and intangible assets	165,403		152,405

Capital expenditures related to equity investees						Capital expenditures related to equity investees	2,976		—
Total capital expenditures						Total capital expenditures	$	168,379	$	152,405

Expenditures for capital assets to grow the partnership distribution will depend on our access to debt and equity capital. We will look for opportunities to acquire assets from other parties that meet our criteria for stable cash flows. We continue to pursue a long-term growth strategy that may require significant capital.

Growth Capital Expenditures

On September 23, 2019, we announced the GOP. ~~We entered into agreements with GSO for the purchase of up to approximately $350 million of preferred units (or 350,000 preferred units) of Alkali Holdings.~~ The ~~proceeds received from GSO will fund up to 100% of the~~ anticipated ~~cost of the GOP. On April 14, 2020, we entered into an amendment to our agreements with GSO to, among other things, extend the construction timeline of the GOP by one year. The extended~~ completion date of the project is ~~anticipated in~~ the ~~second half~~third quarter of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to GSO. As part of the amendment, the commitment period was increased to four years, and the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. The Alkali Holdings preferred unitholders receive PIK distributions in lieu of cash distributions during the new anticipated construction period. As of June 30, 2021 we had issued 201,705 Alkali Holdings preferred units. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year.

~~Except for~~ During the fourth quarter of 2021, we made the decision to fund the remaining capital expenditures associated with the GOP internally.

During 2022, we ~~do not anticipate spending material~~entered into definitive agreements to provide transportation services for 100% of the crude oil production associated with two separate standalone deepwater developments that have a combined production capacity of

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approximately 160,000 barrels per day. In conjunction with these agreements, we expect to spend gross capital expenditures of approximately $600 million (or approximately $500 million net to our ownership interests) over the next three years to: (i) expand the current capacity of the CHOPS pipeline; and (ii) construct a new 100% owned, approximately 105 mile, 20” diameter crude oil pipeline (the “SYNC pipeline”) to connect one of the developments to our existing asset footprint in the Gulf of Mexico. We plan to complete the construction in line with the producers’ plan for first oil achievement, which is currently expected in late 2024 or 2025. The producer agreements include long term take-or-pay arrangements and, accordingly, we are able to receive a project completion credit for purposes of calculating the leverage ratio under our senior secured credit facility throughout the construction period.

We plan to fund our estimated growth capital expenditures ~~on any individual projects during~~utilizing the ~~rest~~available borrowing capacity under our Revolving Loan and our recurring cash flows from operations, which we anticipate to increase throughout 2022 and into 2023 as a result of ~~2021.~~increased offshore volumes from King’s Quay and Argos, favorable export pricing in our Alkali Business, and the restart of our original and expanded Granger facility in 2023.

Maintenance Capital Expenditures

Maintenance capital expenditures incurred during ~~2021~~2022 primarily ~~relate~~related to expenditures in our ~~Alkali Business, our~~ marine transportation segment to replace and upgrade certain equipment associated with our barge and fleet vessels during our planned and unplanned dry-docks and in our ~~offshore transportation segment. Our~~ Alkali Business, which is included in our sodium minerals and sulfur services segment, ~~incurs expenditures to maintain its equipment and facilities~~ due to the ~~nature of its operations. Our marine~~costs to maintain our related equipment and facilities. Additionally, our offshore transportation ~~segment incurs expenditures as we frequently replace and upgrade certain equipment associated with our barge and vessel fleet during our planned and unplanned dry-docks. Additionally, we incurred~~assets incur maintenance capital expenditures into replace, maintain and upgrade equipment at certain of our offshore ~~transportation segment to replace certain pipeline~~platforms and ~~platform equipment and complete the installation of a bypass to allow our CHOPS pipeline to resume operations in the 2021 Quarter.~~pipelines that we operate. See further discussion under ~~"Available~~“Available Cash before ~~Reserves"~~Reserves” for how such maintenance capital utilization is reflected in our calculation of Available Cash before Reserves.

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Distributions to Unitholders

On ~~August~~May 13, ~~2021,~~2022, we ~~will pay~~paid a distribution of $0.15 per unit related to the first quarter of 2022. With respect to our Class A Convertible Preferred Units, we declared a quarterly cash distribution of $0.7374 per preferred unit (or $2.9496 on an annualized basis) for each preferred unit held of record. These distributions were paid on May 13, 2022 to unitholders holders of record at the close of business April 29, 2022.

On July 12, 2022, we announced the distribution of $0.15 per common unit totaling $18.4 million with respect to the ~~2021 Quarter. Information on our recent distribution history is included in~~ ~~Note 10~~ ~~to our Unaudited Condensed Consolidated Financial Statements.~~

~~With respect to our Class A Convertible Preferred Units, we declared~~2022 Quarter and a ~~quarterly cash~~ distribution of $0.7374 per Class A Convertible Preferred Unit (or $2.9496 on an annualized basis) for each Class A Convertible Preferred Unit held of record. These distributions will be payable on August ~~13, 2021~~12, 2022 to unitholders of record at the close of business on July ~~30, 2021.~~29, 2022. Information on our recent distribution history is included in Note 10 to our Unaudited Condensed Consolidated Financial Statements.

Guarantor Summarized Financial Information

Our $2.9 billion aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.'s’s current and future 100% ~~Guarantor Subsidiaries. The assets~~ owned ~~by Genesis Free State Pipeline, LLC were sold on October 30, 2020~~domestic subsidiaries (the “Guarantor Subsidiaries”), except GA ORRI and ~~the ownership of Genesis NEJD Pipeline LLC's pipeline was transferred in October 2020. Genesis NEJD Pipeline LLC is 100% owned by Genesis Energy, L.P., the parent company.~~GA ORRI Holdings and certain other subsidiaries. The remaining non-guarantor subsidiaries are indirectly owned by Genesis Crude Oil, L.P., a Guarantor Subsidiary. The Guarantor Subsidiaries largely own the assets that we use to operate our ~~business other than our Alkali Business.~~ business. As a general rule, the assets and credit of our unrestricted subsidiaries are not available to satisfy the debts of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries, and the liabilities of our unrestricted subsidiaries do not constitute obligations of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries except, in the case of Alkali Holdings and Genesis Energy, L.P., to the extent agreed to in the Services Agreement. Genesis Energy Finance Corporation has no independent assets or operations.Subsidiaries. See Note 9 for additional information regarding our consolidated debt obligations.

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 senior secured credit facility, or liquidation or dissolution of such Guarantor Subsidiary (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 Genesis Energy, L.P.

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The rights of holders of our senior unsecured notes against the Guarantor Subsidiaries may be limited under the U.S. Bankruptcy Code or state fraudulent transfer or conveyance law.

On May 17, 2022, we entered into our credit agreement amendment, which designated GA ORRI and GA ORRI Holdings as unrestricted subsidiaries under our credit agreement. In addition, the credit agreement amendment re-designatedGenesis Alkali Holdings Company LLC, Genesis Alkali Holdings, LLC, Genesis Alkali, LLC and Genesis Alkali Wyoming, LP (the subsidiary entities that own our Alkali Business, other than the ORRI Interests) as restricted entities and guarantors of our credit agreement. On May 17, we designated GA ORRI and GA ORRI Holdings as unrestricted subsidiaries and reclassified the entities that originally held our Alkali Business as restricted subsidiaries under the indentures governing our senior unsecured notes. The Alkali Business was historically presented as non-guarantor subsidiaries and because of such designation will now be presented as guarantor subsidiaries. The changes made did not impact the Company’s previously reported consolidated net operating results, financial position, or cash flows.

The summarized financial information for Genesis Energy, L.P. and the Guarantor Subsidiaries on a combined basis have been retrospectively adjusted to reflect these updates to our guarantor subsidiaries as though the Alkali Business had been presented as guarantor subsidiaries in the periods presented.

The following is the summarized financial information for Genesis Energy, L.P. and the Guarantor Subsidiaries on a combined basis after elimination of intercompany transactions, which includes related receivable and payable balances, and the investment in and equity earnings from the Non-Guarantor Subsidiaries.

Balance Sheets Genesis Energy, L.P. and Guarantor Subsidiaries
June 30, 2021 December 31, 2020
ASSETS:
Current assets $ 368,126 $ 313,328
Fixed assets, net 3,082,195 3,115,492
Non-current assets 826,504 861,230
LIABILITIES AND CAPITAL:(1)
Current liabilities 381,264 266,688
Non-current liabilities 3,694,962 3,710,044
Class A Convertible Preferred Units 790,115 790,115


Balance Sheets	Genesis Energy, L.P. and Guarantor Subsidiaries
	June 30, 2022
ASSETS:
Current assets	$	561,927
Fixed assets and mineral leaseholds, net	3,581,435
Non-current assets	879,855

LIABILITIES AND CAPITAL:(1)
Current liabilities	489,014
Non-current liabilities	3,369,313
Class A Convertible Preferred Units	790,115


Statement of Operations	Genesis Energy, L.P. and Guarantor Subsidiaries
	Six Months Ended June 30, 2022
Revenues	$	1,296,155
Operating costs	1,205,840
Operating income	90,315
Income before income taxes	20,038
Net income(1)	19,180

Less: Accumulated distributions to Class A Convertible Preferred Units	(37,368)
Net loss attributable to common unitholders	(18,188)

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Statements of Operations Genesis Energy, L.P. and Guarantor Subsidiaries
Six Months Ended
June 30, 2021 Twelve Months Ended
December 31. 2020
Revenues $ 679,668 $ 1,156,428
Operating costs 644,271 1,421,674
Operating income (loss) 35,397 (265,246)
Loss before income taxes (82,629) (408,717)
Net loss(1)
(83,366) (409,951)
Less: Accumulated distributions to Class A Convertible Preferred Units (37,368) (74,736)
Net loss available to common unitholders (120,734) (484,687)

~~(1)~~ There are no noncontrolling interests held at the Issuer or Guarantor Subsidiaries for ~~either~~the period presented.

Excluded from non-current assets in the table above ~~are $63.2 million and $95.7~~is $8.2 million of net intercompany receivables due to Genesis Energy, L.P. and the Guarantor Subsidiaries from the Non-Guarantor Subsidiaries as of June 30, ~~2021 and December 31, 2020, respectively.~~2022.

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Non-GAAP Financial Measure Reconciliations

For definitions and discussion of our Non-GAAP financial measures refer to the ~~"Non-GAAP~~“Non-GAAP Financial ~~Measures"~~Measures” as later discussed and defined.

Available Cash before Reserves for the periods presented below was as follows:


		Three Months Ended June 30,					Three Months Ended June 30,
		2021		2020			2022		2021
		(in thousands)					(in thousands)
Net loss attributable to Genesis Energy, L.P.		$	(41,682)	$	(326,714)
Net income (loss) attributable to Genesis Energy, L.P.						Net income (loss) attributable to Genesis Energy, L.P.	$	35,347	$	(41,682)
Income tax expense	Income tax expense	525		795		Income tax expense	571		525
Depreciation, depletion, amortization and accretion	Depreciation, depletion, amortization and accretion	69,684		82,580		Depreciation, depletion, amortization and accretion	76,277		69,684
Impairment expense		—		277,495

Plus (minus) Select Items, net	Plus (minus) Select Items, net	47,440		40,809		Plus (minus) Select Items, net	51,351		47,440
Maintenance capital utilized (1)	Maintenance capital utilized (1)	(13,300)		(9,900)		Maintenance capital utilized(1)	(14,150)		(13,300)
Cash tax expense	Cash tax expense	(195)		(150)		Cash tax expense	(150)		(195)
Distributions to preferred unitholders	Distributions to preferred unitholders	(18,684)		(18,684)		Distributions to preferred unitholders	(18,684)		(18,684)
Redeemable noncontrolling interest redemption value adjustments (2)	Redeemable noncontrolling interest redemption value adjustments (2)	5,766		4,159		Redeemable noncontrolling interest redemption value adjustments(2)	22,620		5,766
Gain on sale of asset, net to our ownership interest(3)						Gain on sale of asset, net to our ownership interest(3)	(32,000)		—

Available Cash before Reserves	Available Cash before Reserves	$	49,554	$	50,390	Available Cash before Reserves	$	121,182	$	49,554

(1)For a description of the term ~~"maintenance~~“maintenance capital ~~utilized"~~utilized”, please see the definition of the term ~~"Available~~“Available Cash before ~~Reserves"~~Reserves” discussed below. Maintenance capital expenditures in the 2022 Quarter and 2021 Quarter ~~and 2020 Quarter~~ were ~~$23.8~~$24.3 million and ~~$13.0~~$23.8 million, respectively.

(2)Includes PIK distributions ~~attributable to the period~~ and accretion on the redemption ~~feature.~~feature attributable to each period, and valuation adjustments to the redemption feature during the 2022 Quarter.

(3)On April 29, 2022, we sold our Independence HUB platform and recognized a gain on the sale of $40.0 million, of which $32.0 million was attributable to our 80% ownership interest.

We define Available Cash before Reserves (“Available Cash before Reserves”) as ~~net~~Net income (loss) attributable to Genesis Energy, L.P. before interest, taxes, depreciation, depletion and amortization (including impairment, write-offs, accretion and similar items) after eliminating other non-cash revenues, expenses, gains, losses and charges (including any loss on asset dispositions), plus or minus certain other select items that we view as not indicative of our core operating results (collectively, “Select Items”), as adjusted for certain items, the most significant of which in the relevant reporting periods have been the sum of maintenance capital utilized, ~~net~~ interest ~~expense, cash tax~~ expense and cash ~~distributions to our preferred unitholders.~~tax expense. Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. The most significant Select Items in the relevant reporting periods are set forth below.

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			Three Months Ended June 30,						Three Months Ended June 30,
			2021		2020				2022		2021
			(in thousands)						(in thousands)
I.	I.	Applicable to all Non-GAAP Measures					I.	Applicable to all Non-GAAP Measures
		Differences in timing of cash receipts for certain contractual arrangements (1)	$	6,446	$	11,638		Differences in timing of cash receipts for certain contractual arrangements(1)	$	16,477	$	6,446
		Distribution from unrestricted subsidiaries not included in income (2)	17,500		2,294			Distribution from unrestricted subsidiaries not included in income(2)	32,000		17,500

		Certain non-cash items:						Certain non-cash items:
		Unrealized losses on derivative transactions excluding fair value hedges, net of changes in inventory value (3)	14,750		21,108			Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value(3)	(8,319)		14,750
								Loss on debt extinguishment	501		—
		Adjustment regarding equity investees (4)	7,692		5,776			Adjustment regarding equity investees(4)	4,160		7,692
		Other	(67)		2,183			Other	(589)		(67)
		Sub-total Select Items, net	46,321		42,999			Sub-total Select Items, net	44,230		46,321
II.	II.	Applicable only to Available Cash before Reserves					II.	Applicable only to Available Cash before Reserves
		Certain transaction costs (5)	621		21			Certain transaction costs(5)	5,330		621

		Other	498		(2,211)			Other	1,791		498
		Total Select Items, net (6)	$	47,440	$	40,809		Total Select Items, net(6)	$	51,351	$	47,440

(1)Includes the difference in timing of cash receipts from or billings to customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

(2)The 2022 Quarter includes $32.0 million in cash receipts associated with the sale of the Independence Hub platform by our 80% owned unrestricted subsidiary (as defined under our credit agreement), Independence Hub, LLC. The 2021 Quarter includes $17.5 million in cash receipts associated with principal repayments on our previously owned NEJD pipeline not included in income. ~~The 2020 Quarter includes cash payments~~We received ~~from~~ the last principal payment associated with our previously owned NEJD pipeline in the fourth quarter of ~~$2.3 million not included in income.~~2021. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our senior secured credit facility.

(3)The ~~2021~~2022 Quarter includes ~~a $14.3~~unrealized losses of $2.3 million from the valuation of our commodity derivative transactions (excluding fair value hedges) and an unrealized ~~loss~~gain of $10.7 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred ~~Units and the 2020~~Units. The 2021 Quarter includes ~~a $21.8 million~~an unrealized loss of $14.3 million from the valuation of the embedded ~~derivative.~~derivative associated with our Class A Convertible Preferred Units.

(4)Represents the net effect of adding distributions from equity investees and deducting earnings of equity investees net to us.

(5)Represents transaction costs relating to certain merger, acquisition, divestiture, transition, and financing transactions incurred in advance of ~~acquisition.~~the associated transaction.

(6)Represents Select Items applicable to Adjusted EBITDA and Available Cash before Reserves.

Non-GAAP Financial Measures

General

To help evaluate our business, we use the non-generally accepted accounting principle (“non-GAAP”) financial measure of Available Cash before Reserves. We also present total Segment Margin as if it were a non-GAAP measure. Our non-GAAP measures may not be comparable to similarly titled measures of other companies because such measures may include or exclude other specified items. The schedules above provide reconciliations of Available Cash before Reserves to its most directly comparable financial measures calculated in accordance with generally accepted accounting principles in the United States of America (GAAP). A reconciliation of Net Income (Loss) attributable Genesis Energy, L.P. to total Segment Margin ~~to net loss~~ is also included in our segment disclosure in Note 12 to our Unaudited Condensed Consolidated Financial Statements. Our non-GAAP financial measures should not be considered (i) as alternatives to GAAP measures of liquidity or financial performance or (ii) as being singularly important in any particular context; they should be considered in a broad context with other quantitative and qualitative information. Our Available Cash before Reserves and total Segment Margin measures are just two of the relevant data points considered from time to time.

When evaluating our performance and making decisions regarding our future direction and actions (including making discretionary payments, such as quarterly distributions) our board of directors and management team has access to a wide range of historical and forecasted qualitative and quantitative information, such as our financial statements; operational information; various non-GAAP measures; internal forecasts; credit metrics; analyst opinions; ~~performance,~~performance; liquidity and similar measures; income; cash ~~flow; and~~flow expectations for ~~us,~~us; and certain information regarding some of our peers. Additionally, our board of

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directors and management team analyze, and place different weight on, various factors from time to time. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts and other market participants. We attempt to provide adequate information to allow each individual investor and other external user to reach her/his own conclusions regarding our actions without providing so much information as to overwhelm or confuse such investor or other external user. Our non-GAAP financial measures should not be considered as an alternative to GAAP

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measures such as net income, operating income, cash flow from operating activities or any other GAAP measure of liquidity or financial performance.

Segment Margin

Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes where relevant and capital investment. We define Segment Margin as revenues less product costs, operating expenses and segment general and administrative expenses ~~after eliminating gain or loss on sale~~(all of ~~assets,~~which are net of the effects of our noncontrolling interest holders), plus or minus applicable Select Items. Although we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes where relevant and capital investment.

A reconciliation of Net income (loss) attributable to Genesis Energy, L.P. to total Segment Margin ~~to net loss~~ is included in our segment disclosure in Note 12 to our Unaudited Condensed Consolidated Financial Statements, as well as previously in this Item 2.

Available Cash before Reserves

Purposes, Uses and Definition

Available Cash before Reserves, often referred to by others as distributable cash flow, is a quantitative standard used throughout the investment community with respect to publicly traded partnerships and is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:

(1) the financial performance of our assets;

(2) our operating performance;

(3) the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;

(4) the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and

(5) our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.

Disclosure Format Relating to Maintenance Capital

We use a modified format relating to maintenance capital requirements because our maintenance capital expenditures vary materially in nature (discretionary vs. non-discretionary), timing and amount from time to time. We believe that, without such modified disclosure, such changes in our maintenance capital expenditures could be confusing and potentially misleading to users of our financial information, particularly in the context of the nature and purposes of our Available Cash before Reserves measure. Our modified disclosure format provides those users with information in the form of our maintenance capital utilized measure (which we deduct to arrive at Available Cash before Reserves). Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Requirements

Maintenance ~~Capital Expenditures~~

~~Maintenance~~ capital expenditures are capitalized costs that are necessary to maintain the service capability of our existing assets, including the replacement of any system component or equipment which is worn out or obsolete. Maintenance capital expenditures can be discretionary or non-discretionary, depending on the facts and circumstances.

~~Initially,~~Prior to 2014, substantially all of our maintenance capital expenditures were (a) related to our pipeline assets and similar infrastructure, (b) non-discretionary in nature and (c) immaterial in amount as compared to our Available Cash before Reserves measure. Those historical expenditures were non-discretionary (or mandatory) in nature because we had very little (if any) discretion as to whether or when we incurred them. We had to incur them in order to continue to operate the related pipelines in a safe and reliable manner and consistently with past practices. If we had not made those expenditures, we would not have been able to continue to operate all or portions of those pipelines, which would not have been economically feasible.

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An example of a non-discretionary (or mandatory) maintenance capital expenditure would be replacing a segment of an old pipeline because one can no longer operate that pipeline safely, legally and/or economically in the absence of such replacement.

AsBeginning with 2014, we ~~exist today,~~believe a substantial amount of our maintenance capital expenditures from time to time have been and will continue to be (a) related to our assets other than pipelines, such as our marine vessels, trucks and similar assets, (b) discretionary in nature and (c) potentially material in amount as compared to our Available Cash before Reserves measure. Those expenditures will be discretionary (or non-mandatory) in nature because we will have significant discretion as to whether or when we incur them.

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We will not be forced to incur them in order to continue to operate the related assets in a safe and reliable manner. If we chose not to make those expenditures, we would be able to continue to operate those assets economically, although in lieu of maintenance capital expenditures, we would incur increased operating expenses, including maintenance expenses. An example of a discretionary (or non-mandatory) maintenance capital expenditure would be replacing an older marine vessel with a new marine vessel with substantially similar specifications, even though one could continue to economically operate the older vessel in spite of its increasing maintenance and other operating expenses.

In summary, as we continue to expand certain non-pipeline portions of our business, we are experiencing changes in the nature (discretionary vs. non-discretionary), timing and amount of our maintenance capital expenditures that merit a more detailed review and analysis than was required historically. Management’s ~~recently~~ increasing ability to determine if and when to incur certain maintenance capital expenditures is relevant to the manner in which we analyze aspects of our business relating to discretionary and non-discretionary expenditures. We believe it would be inappropriate to derive our Available Cash before Reserves measure by deducting discretionary maintenance capital expenditures, which we believe are similar in nature in this context to certain other discretionary expenditures, such as growth capital expenditures, distributions/dividends and equity buybacks. Unfortunately, not all maintenance capital expenditures are clearly discretionary or non-discretionary in nature. Therefore, we developed a measure, maintenance capital utilized, that we believe is more useful in the determination of Available Cash before Reserves. Our maintenance capital utilized measure, which is described in more detail below, constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Utilized

We believe our maintenance capital utilized measure is the most useful quarterly maintenance capital requirements measure to use to derive our Available Cash before Reserves measure. We define our maintenance capital utilized measure as that portion of the amount of previously incurred maintenance capital expenditures that we utilize during the relevant quarter, which would be equal to the sum of the maintenance capital expenditures we have incurred for each project/component in prior quarters allocated ratably over the useful lives of those projects/components.

Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period. Because we did not initially use our maintenance capital utilized measure before 2014, our ~~future~~ maintenance capital utilized calculations will reflect the utilization of solely those maintenance capital expenditures incurred since December 31, 2013.

~~Commitments and Off-Balance Sheet Arrangements~~Critical Accounting Estimates

~~Contractual Obligations and Commercial Commitments~~

There have been no new or material changes to the ~~commitments and obligations reflected~~critical accounting estimates discussed in our Annual Report ~~other than~~that are of significance, or potential significance, to the ~~additional $250 million issuance of our 2027 Notes and our new credit agreement (including its extended maturity), which are discussed in further detail in~~ ~~Note 9~~.

~~Off-Balance Sheet Arrangements~~

We have no off-balance sheet arrangements, special purpose entities, or financing partnerships, other than as disclosed under “Contractual Obligations and Commercial Commitments” in our Annual Report, nor do we have any debt or equity triggers based upon our unit or commodity prices.Company.

Forward Looking Statements

The statements in this Quarterly Report on Form 10-Q that are not historical information may be “forward looking statements” as defined under federal law. All statements, other than historical facts, included in this document that address activities, events or developments that we expect or anticipate will or may occur in the future, including things such as plans for growth of the business, future capital expenditures, competitive strengths, goals, references to future goals or intentions, estimated or projected future financial performance, ~~our expectations regarding the potential impact of the Covid-19 pandemic, the impact of our cost saving measures and the amount of such cost savings,~~ and other such references are forward-looking statements, and historical performance is not necessarily indicative of future performance. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. They use words such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “could,” “plan,” “position,” “projection,” “strategy,” “should” or “will,” or the negative of those terms or other variations of them or by comparable terminology. In particular, statements, expressed or implied, concerning future actions, conditions or events or future operating results or the ability to generate sales, income or cash flow are forward-looking statements. Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future actions, conditions or events and future results of operations may differ materially from those expressed in these forward-looking statements. Many of the factors that will determine these results are beyond our ability or the ability of our affiliates to control or predict. Specific factors that could cause actual results to differ from those in the forward-looking statements include, among others:

•demand for, the supply of, our assumptions about, changes in forecast data for, and price trends related to crude oil, liquid petroleum, natural gas, NaHS, soda ash, and caustic soda, all of which may be affected by

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economic activity, capital expenditures by energy producers, weather, alternative energy sources, international events (including the war in Ukraine), global pandemics, ~~(including Covid-19),~~inflation, the actions of OPEC and other oil exporting nations, conservation and technological advances;

•our ability to successfully execute our business and financial strategies;

•our ability to continue to realize cost savings from our ~~recent~~ cost saving measures;

•~~the realized benefits of the preferred equity investment in Alkali Holdings by GSO or our ability to comply with the GOP agreements and maintain control over and ownership of the Alkali Business;~~

•throughput levels and rates;

•changes in, or challenges to, our tariff rates;

•our ability to successfully identify and close strategic acquisitions on acceptable terms (including obtaining third-party consents and waivers of preferential rights), develop or construct infrastructure assets, make cost saving changes in operations and integrate acquired assets or businesses into our existing operations;

•service interruptions in our pipeline transportation systems, processing operations, or mining facilities;

•shutdowns or cutbacks at refineries, petrochemical plants, utilities, individual plants, or other businesses for which we transport crude oil, petroleum, natural gas or other products or to whom we sell soda ash, petroleum, or other products;

•risks inherent in marine transportation and vessel operation, including accidents and discharge of pollutants;

•changes in laws and regulations to which we are subject, including tax withholding issues, regulations regarding qualifying income, accounting pronouncements, and safety, environmental and employment laws and regulations;

•the effects of production declines resulting from a suspension of drilling in the Gulf of Mexico or otherwise;

•the effects of future laws and regulations;

•planned capital expenditures and availability of capital resources to fund capital expenditures, and our ability to access the credit and capital markets to obtain financing on terms we deem acceptable;

•our inability to borrow or otherwise access funds needed for operations, expansions or capital expenditures as a result of our credit agreement and the indentures governing our notes, which contain various affirmative and negative covenants;

•loss of key personnel;

•cash from operations that we generate could decrease or fail to meet expectations, either of which could reduce our ability to pay quarterly cash distributions (common and preferred) at the current level or to increase quarterly cash distributions in the future;

•an increase in the competition that our operations encounter;

•cost and availability of insurance;

•hazards and operating risks that may not be covered fully by insurance;

•our financial and commodity hedging arrangements, which may reduce our earnings, profitability and cash flow;

•changes in global economic conditions, including capital and credit markets conditions, inflation and interest rates;

•the impact of natural disasters, international military conflicts (such as the conflict in Ukraine), pandemics (including Covid-19), epidemics, accidents or terrorism, and actions taken by governmental authorities and other third parties in response thereto, on our business financial condition and results of operations;

•reduction in demand for our services resulting in impairments of our assets;

•changes in the financial condition of customers or counterparties;

•adverse rulings, judgments, or settlements in litigation or other legal or tax matters;

•the treatment of us as a corporation for federal income tax purposes or if we become subject to entity-level taxation for state tax purposes;

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•the potential that our internal controls may not be adequate, weaknesses may be discovered or remediation of any identified weaknesses may not be successful and the impact these could have on our unit price; and

•a cyberattack involving our information systems and related infrastructure, or that of our business associates.

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You should not put undue reliance on any forward-looking statements. When considering forward-looking statements, please review the risk factors described under “Risk Factors” discussed in Item 1A of our Annual Report . These risks may also be specifically described in our Quarterly Reports on Form 10-Q, Current Reports on Form 8-K (or any amendments to those reports) and other documents that we may file from time to time with the SEC. New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time to time, and it is not possible for us to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those contained in any forward-looking statement. Except as required by applicable securities laws, we do not intend to update these forward-looking statements and information.

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Item 3. Quantitative and Qualitative Disclosures about Market Risk

The following should be read in conjunction with Quantitative and Qualitative Disclosures About Market Risk included under Item 7A in our Annual Report. There have been no material changes that would affect the quantitative and qualitative disclosures provided therein. Also, see Note 15 to our Unaudited Condensed Consolidated Financial Statements for additional discussion related to derivative instruments and hedging activities.

Item 4. Controls and Procedures

We maintain disclosure controls and procedures and internal controls designed to ensure that information required to be disclosed in our filings under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in the ~~SEC's~~SEC’s rules and forms. Our chief executive officer and chief financial officer, with the participation of our management, have evaluated our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form ~~10-Q~~10-Q. Based upon that evaluation, management identified a material weakness in our internal control over financial reporting as we did not effectively operate control activities to reach the appropriate conclusion on the accounting treatment for certain revenue contract amendments executed during the second quarter of 2022. Solely as a result of this material weakness, our chief executive officer and ~~have determined~~chief financial officer concluded that ~~such~~our disclosure controls and procedures ~~are~~were not effective as of the last day of the period covered by this report. This material weakness did not, however, result in ~~ensuring that~~a misstatement to the reported consolidated financial statements, and notwithstanding the material ~~information required to be disclosed~~weakness, management, including our chief executive officer and chief financial officer, believes the consolidated financial statements included in this Quarterly Report on Form 10-Q fairly represent in all material respects our financial condition, results of operations and cash flows at and for the periods presented in accordance with GAAP.

A material weakness is ~~accumulated and communicated~~a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.

In order to ~~them and~~address the material weakness described above, our management intends to ~~allow timely decisions regarding required disclosures.~~implement a remediation plan to address the control deficiency that led to this material weakness, including plans for additional review procedures, enhancements in the relevant accounting processes and continuing education associated with the review of revenue contracts to evaluate, resolve and document the proper accounting in accordance with GAAP.

~~There were~~Changes in Internal Control Over Financial Reporting

Except as noted above, there have been no changes in internal control over financial reporting during the ~~2021 Quarter~~quarter ended June 30, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Information with respect to this item has been incorporated by reference from our Annual Report on Form 10-K for the year ended December 31, ~~2020~~2021 (the ~~"Annual Report"~~“Annual Report”). There have been no material developments in legal proceedings since the filing of such Form 10-K.

Item 103 of SEC Regulation S-K requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that we reasonably believe will exceed a specified threshold. Pursuant to recent SEC amendments to this item, we will be using a threshold of $1 million for such proceedings. We believe that such threshold is reasonably designed to result in disclosure of environmental proceedings that are material to our business or financial condition. Applying this threshold, there are no environmental matters to disclose for this period.

Item 1A. Risk Factors

There has been no material change in our risk factors as previously disclosed in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2020.~~2021.

For additional information about our risk factors, see Item 1A of our Annual Report, as well as any other risk factors contained in other filings with the SEC, including Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and Form 8-K/A and other documents that we may file from time to time with the SEC.

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

There were no sales of unregistered equity securities during the ~~2021~~2022 Quarter.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Information regarding mine safety and other regulatory action at our mines in Green River and Granger, Wyoming is included in Exhibit 95 to this Form 10-Q.

Item 5. Other Information

None.

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Item 6. Exhibits.

(a) Exhibits


	3.1	Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.1 to Amendment No. 2 of the Registration Statement on Form S-1 filed on November 15, 1996, File No. 333-11545).
	3.2	Amendment to the Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.2 to the ~~Company's~~Company ’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2011, File No. 001-12295).
	3.3	Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 5.1 to the ~~Company's~~Company ’s Current Report on Form 8-K dated January 3, 2011, File No. 001-12295).
	3.4	First Amendment to Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P., dated September 1, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated September 7, 2017, File No. 001-12295).
	3.5	Second Amendment to Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P., dated December 31, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated January 4, 2018, File No. 001-12295).
	3.6	Certificate of Conversion of Genesis Energy, Inc. a Delaware corporation, into Genesis Energy, LLC, a Delaware limited liability company (incorporated by reference to Exhibit 3.1 to the ~~Company's~~Company ’s Current Report on Form 8-K dated January 7, 2009, File No. 001-12295).
	3.7	Certificate of Formation of Genesis Energy, LLC (formerly Genesis Energy, Inc.) (incorporated by reference to Exhibit 3.2 to the ~~Company's~~Company ’s Current Report on Form 8-K dated January 7, 2009, File No. 001-12295).
	3.8	Second Amended and Restated Limited Liability Company Agreement of Genesis Energy, LLC dated December 28, 2010 (incorporated by reference to Exhibit 5.2 to the ~~Company's~~Company ’s Current Report on Form 8-K dated January 3, 2011, File No. 001-12295).
	3.9	Certificate of Incorporation of Genesis Energy Finance Corporation, dated as of November 26, 2006 (incorporated by reference to Exhibit 3.7 to Registration Statement on Form S-4 filed on September 26, 2011, File No. 333-177012).
	3.10	Bylaws of Genesis Energy Finance Corporation (incorporated by reference to Exhibit 3.8 to Registration Statement on Form S-4 filed on September 26, 2011, File No. 333-177012).
	4.1	Form of Unit Certificate of Genesis Energy, L.P. (incorporated by reference to Exhibit 4.1 to the ~~Company's~~Company ’s Annual Report on Form 10-K for the year ended December 31, 2007, File No. 001-12295).
*	4.2	~~Sixteenth~~Seventeenth Supplemental Indenture for 5.625% Senior Notes due 2024, dated as of June 28, 2021, among Genesis Energy, L.P., Genesis Energy Finance Corporation, the Guarantors named therein and Regions Bank, as trustee.
*	4.3	~~Sixteenth~~Seventeenth Supplemental Indenture for 6.50% Senior Notes due 2025, 6.250% Senior Notes due 2026, 7.750% Senior Notes due 2028, and 8.0% Senior Notes due 2027, dated as of June 28, 2021, among Genesis Energy, L.P., Genesis Energy Finance Corporation, the Guarantors named therein and Regions Bank, as trustee.
*	10.1	Second Amendment and Consent to Fifth Amended and Restated Credit Agreement, dated as of May 17, 202 2 , among Genesis Energy, L.P., as borrower, Wells Fargo Bank, National Association, as administrative agent, Bank of America, N.A., as syndication agent, and the lenders party thereto.
*	22.1	List of Issuers and Guarantor Subsidiaries
*	31.1	Certification by Chief Executive Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
*	31.2	Certification by Chief Financial Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
*	32	Certification by Chief Executive Officer and Chief Financial Officer Pursuant to Rule 13a-14(b) of the Securities Exchange Act of 1934.
*	95	Mine Safety Disclosures.
	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	XBRL Schema Document.
	101.CAL	XBRL Calculation Linkbase Document.
	101.LAB	XBRL Label Linkbase Document.
	101.PRE	XBRL Presentation Linkbase Document.
	101.DEF	XBRL Definition Linkbase Document.
	104	Cover Page Interactive Data File (formatted as Inline XBRL).


*			Filed herewith

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SIGNATURES

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


						GENESIS ENERGY, L.P. (A Delaware Limited Partnership)

			By:			GENESIS ENERGY, LLC, as General Partner


Date:	August ~~4, 2021~~2, 2022	By:	/s/ ROBERT V. DEERE
			Robert V. Deere
			Chief Financial Officer
			(Duly Authorized Officer)


	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2020	122,579	$	829,326	$	(1,113)	$	(9,365)	$	818,848


Net income (loss)	—	(75,906)		134		—		(75,772)

Cash distributions to partners	—	(36,774)		—		—		(36,774)
Cash contributions from noncontrolling interests	—	—		385		—		385

Other comprehensive income	—	—		—		243		243
Distributions to Class A Convertible Preferred unitholders	—	(37,368)		—		—		(37,368)


Partners' capital, June 30, 2021	122,579	$	679,278	$	(594)	$	(9,122)	$	669,562
	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2019	122,579	$	1,443,320	$	(3,718)	$	(8,431)	$	1,431,171
Net loss	—	(301,805)		(26)		—		(301,831)

Cash distributions to partners	—	(85,805)		—		—		(85,805)
Cash contributions from noncontrolling interests	—	—		1,844		—		1,844

Other comprehensive income	—	—		—		243		243
Distributions to Class A Convertible Preferred unitholders	—	(37,368)		—		—		(37,368)

Partners' capital, June 30, 2020	122,579	$	1,018,342	$	(1,900)	$	(8,188)	$	1,008,254


	Three Months Ended June 30, 2020
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	64,964	$	0	$	56,720	$	21,845	$	143,529
Product Sales	0		172,410		0		52,314		224,724
Refinery Services	0		20,214		0		0		20,214
	$	64,964	$	192,624	$	56,720	$	74,159	$	388,467


	Offshore Pipeline Transportation		Onshore Facilities and Transportation
Remainder of 2021	$	31,048	$	9,604
2022	75,623		4,698
2023	63,982		0
2024	56,326		0
2025	60,311		0
Thereafter	97,761		0
Total	$	385,051	$	14,302


	June 30, 2021		December 31, 2020
Crude oil pipelines and natural gas pipelines and related assets	$	2,821,996	$	2,811,030
Alkali facilities, machinery, and equipment	641,619		622,598
Onshore facilities, machinery, and equipment	268,689		267,810
Transportation equipment	21,348		19,470
Marine vessels	1,011,171		998,553
Land, buildings and improvements	221,146		219,382
Office equipment, furniture and fixtures	22,185		22,001
Construction in progress	260,742		170,740
Other	43,261		41,891
Fixed assets, at cost	5,312,157		5,173,475
Less: Accumulated depreciation	(1,437,510)		(1,322,141)
Net fixed assets	$	3,874,647	$	3,851,334


Remainder of	2021	$	4,975
	2022	$	9,384
	2023	$	9,128
	2024	$	9,783
	2025	$	10,487


	June 30, 2021		December 31, 2020
BALANCE SHEET DATA:
Assets
Current assets	$	17,546	$	30,465
Fixed assets, net	167,764		171,732
Other assets	5,447		4,673
Total assets	$	190,757	$	206,870
Liabilities and equity
Current liabilities	$	13,649	$	9,958
Other liabilities	229,836		237,595
Equity (Deficit)	(52,728)		(40,683)
Total liabilities and equity	$	190,757	$	206,870


Remainder of	2021	$	5,673
	2022	$	11,244
	2023	$	10,976
	2024	$	10,661
	2025	$	10,494


Year	Principal Due (1)
2021	$	15,000
2022	60,000
2023	100,000
2024	125,000


Statements of Operations	Genesis Energy, L.P. and Guarantor Subsidiaries
	Six Months Ended June 30, 2021		Twelve Months Ended December 31. 2020
Revenues	$	679,668	$	1,156,428
Operating costs	644,271		1,421,674
Operating income (loss)	35,397		(265,246)
Loss before income taxes	(82,629)		(408,717)
Net loss(1)	(83,366)		(409,951)

Less: Accumulated distributions to Class A Convertible Preferred Units	(37,368)		(74,736)
Net loss available to common unitholders	(120,734)		(484,687)