10-Q

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 September 30, 2022

OR

☐ 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.)
811 Louisiana, Suite 1200,
	Houston	,	TX		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  ¨

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	x	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 October 26, 2022.

GENESIS ENERGY, L.P.

TABLE OF CONTENTS

		Page
	PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Condensed Consolidated Balance Sheets as of September 30, 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	8
	3. Revenue Recognition	9
	4. Lease Accounting	10
	5. Inventories	11
	6. Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	12
	7. Equity Investees	13
	8. Intangible Assets	14
	9. Debt	15
	10. Partners’ Capital, Mezzanine Capital and Distributions	17
	11. Net Loss Per Common Unit	20
	12. Business Segment Information	20
	13. Transactions with Related Parties	23
	14. Supplemental Cash Flow Information	24
	15. Derivatives	24
	16. Fair-Value Measurements	27
	17. Commitments and Contingencies	28
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	53
Item 4.	Controls and Procedures	53
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	54
Item 1A.	Risk Factors	54
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	54
Item 3.	Defaults upon Senior Securities	54
Item 4.	Mine Safety Disclosures	54
Item 5.	Other Information	54
Item 6.	Exhibits	55
SIGNATURES		56

2

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

GENESIS ENERGY, L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except units)  

	September 30, 2022		December 31, 2021
	(unaudited)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	5,848	$	19,987
Restricted cash	18,637		5,005
Accounts receivable - trade, net	575,927		400,334
Inventories	92,907		77,958
Other	33,111		39,200
Total current assets	726,430		542,484
FIXED ASSETS, at cost	5,731,630		5,464,040
Less: Accumulated depreciation	(1,711,306)		(1,551,855)
Net fixed assets	4,020,324		3,912,185
MINERAL LEASEHOLDS, net of accumulated depletion	546,175		549,005
EQUITY INVESTEES	285,417		294,050
INTANGIBLE ASSETS, net of amortization	127,201		127,063
GOODWILL	301,959		301,959
RIGHT OF USE ASSETS, net	128,288		140,796
OTHER ASSETS, net of amortization	33,745		38,259
TOTAL ASSETS	$	6,169,539	$	5,905,801
LIABILITIES AND CAPITAL
CURRENT LIABILITIES:
Accounts payable - trade	$	378,367	$	264,316
Accrued liabilities	266,950		232,623
Total current liabilities	645,317		496,939
SENIOR SECURED CREDIT FACILITY	120,200		49,000
SENIOR UNSECURED NOTES, net of debt issuance costs and premium	2,854,874		2,930,505
ALKALI SENIOR SECURED NOTES, net of debt issuance costs and discount	402,254		—
DEFERRED TAX LIABILITIES	15,307		14,297
OTHER LONG-TERM LIABILITIES	373,397		434,925
Total liabilities	4,411,349		3,925,666
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at September 30, 2022 and December 31, 2021	891,909		790,115
Redeemable noncontrolling interests, no units issued and outstanding at September 30, 2022 and 246,394 preferred units issued and outstanding December 31, 2021	—		259,568
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at September 30, 2022 and December 31, 2021	562,373		641,313
Accumulated other comprehensive loss	(5,242)		(5,607)
Noncontrolling interests	309,150		294,746
Total partners’ capital	866,281		930,452
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$	6,169,539	$	5,905,801

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

3

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
REVENUES:
Offshore pipeline transportation	$	89,805	$	69,479	$	239,958	$	207,084
Sodium minerals and sulfur services	312,681		237,651		916,963		702,025
Marine transportation	77,795		48,716		209,889		136,673
Onshore facilities and transportation	240,967		162,975		708,110		498,113
Total revenues	721,248		518,821		2,074,920		1,543,895
COSTS AND EXPENSES:
Onshore facilities and transportation product costs	213,680		129,498		630,985		414,933
Onshore facilities and transportation operating costs	17,697		15,792		50,276		47,887
Marine transportation operating costs	63,074		39,782		165,726		111,986
Sodium minerals and sulfur services operating costs	235,308		196,656		699,847		578,058
Offshore pipeline transportation operating costs	25,410		21,080		74,785		63,060
General and administrative	17,038		14,371		52,825		38,944
Depreciation, depletion and amortization	73,946		67,148		217,125		200,975
Gain on sale of asset	—		—		(40,000)		—
Total costs and expenses	646,153		484,327		1,851,569		1,455,843
OPERATING INCOME	75,095		34,494		223,351		88,052
Equity in earnings of equity investees	13,236		10,301		40,252		45,183
Interest expense	(57,710)		(59,940)		(168,773)		(176,938)
Other income (expense)	(21,388)		1,741		(10,758)		(34,169)
Income (loss) from operations before income taxes	9,233		(13,404)		84,072		(77,872)
Income tax expense	(660)		(423)		(1,535)		(1,170)
NET INCOME (LOSS)	8,573		(13,827)		82,537		(79,042)
Net loss (income) attributable to noncontrolling interests	(5,188)		10		(18,612)		(124)
Net income attributable to redeemable noncontrolling interests	—		(7,082)		(30,443)		(17,639)
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS	$	(15,299)	$	(39,583)	$	(22,570)	$	(152,857)
NET LOSS PER COMMON UNIT (Note 11):
Basic and Diluted	$	(0.12)	$	(0.32)	$	(0.18)	$	(1.25)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
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.

4

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net income (loss)	$	8,573	$	(13,827)	$	82,537	$	(79,042)
Other comprehensive income:
Amortization of prior year service cost	122		122		365		365
Total Comprehensive income (loss)	8,695		(13,705)		82,902		(78,677)
Comprehensive loss (income) attributable to noncontrolling interests	(5,188)		10		(18,612)		(124)
Comprehensive income attributable to redeemable noncontrolling interests	—		(7,082)		(30,443)		(17,639)
Comprehensive income (loss) attributable to Genesis Energy, L.P.	$	3,507	$	(20,777)	$	33,847	$	(96,440)

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

5

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, June 30, 2022	122,579	$	596,059	$	299,846	$	(5,364)	$	890,541
Net income	—	3,385		5,188		—		8,573
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash distributions to noncontrolling interests	—	—		(6,324)		—		(6,324)
Cash contributions from noncontrolling interests	—	—		10,440		—		10,440
Other comprehensive income	—	—		—		122		122
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)
Partners' capital, September 30, 2022	122,579	$	562,373	$	309,150	$	(5,242)	$	866,281
	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners' capital, June 30, 2021	122,579	$	679,278	$	(594)	$	(9,122)	$	669,562
Net loss	—	(20,899)		(10)		—		(20,909)
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash contributions from noncontrolling interests	—	—		172		—		172
Other comprehensive income	—	—		—		122		122
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)
Partners' capital, September 30, 2021	122,579	$	621,308	$	(432)	$	(9,000)	$	611,876

	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	—	33,482		18,612		—		52,094
Cash distributions to partners	—	(55,161)		—		—		(55,161)
Adjustment to valuation of noncontrolling interest in subsidiary	—	(1,209)		1,209		—		—
Cash distributions to noncontrolling interests	—	—		(24,656)		—		(24,656)
Cash contributions from noncontrolling interests	—	—		19,239		—		19,239
Other comprehensive income	—	—		—		365		365
Distributions to Class A Convertible Preferred unitholders	—	(56,052)		—		—		(56,052)
Partners' capital, September 30, 2022	122,579	$	562,373	$	309,150	$	(5,242)	$	866,281
	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)	—	(96,805)		124		—		(96,681)
Cash distributions to partners	—	(55,161)		—		—		(55,161)
Cash contributions from noncontrolling interests	—	—		557		—		557
Other comprehensive income	—	—		—		365		365
Distributions to Class A Convertible Preferred unitholders	—	(56,052)		—		—		(56,052)
Partners' capital, September 30, 2021	122,579	$	621,308	$	(432)	$	(9,000)	$	611,876

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

6

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Nine Months Ended September 30,
	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	82,537	$	(79,042)
Adjustments to reconcile net income (loss) to net cash provided by operating activities -
Depreciation, depletion and amortization	217,125		200,975
Gain on sale of asset	(40,000)		—
Amortization and write-off of debt issuance costs, premium and discount	7,110		9,242
Payments received under previously owned direct financing leases	—		52,500
Equity in earnings of investments in equity investees	(40,252)		(45,183)
Cash distributions of earnings of equity investees	41,496		44,747
Non-cash effect of long-term incentive compensation plans	10,835		5,111
Deferred and other tax liabilities	1,010		630
Unrealized losses on derivative transactions	15,726		30,729
Cancellation of debt income	(8,619)		—
Other, net	14,203		16,191
Net changes in components of operating assets and liabilities (Note 14)	(48,576)		6,457
Net cash provided by operating activities	252,595		242,357
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(303,789)		(217,972)
Cash distributions received from equity investees - return of investment	14,737		24,126
Investments in equity investees	(5,441)		(129)
Proceeds from asset sales	40,281		223
Net cash used in investing activities	(254,212)		(193,752)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	697,000		553,100
Repayments on senior secured credit facility	(625,800)		(763,800)
Net proceeds from issuance of Alkali senior secured notes (Note 9)	408,000		—
Redemption of preferred units (Note 10)	(288,629)		—
Proceeds from issuance of senior unsecured notes (Note 9)	—		259,375
Net proceeds from issuance of preferred units	—		93,100
Repayment of senior unsecured notes (Note 9)	(72,241)		(80,859)
Debt issuance costs	(6,019)		(12,208)
Contributions from noncontrolling interests	19,239		557
Distributions to noncontrolling interests	(24,656)		—
Distributions to common unitholders	(55,161)		(55,161)
Distributions to Class A Convertible Preferred unitholders	(56,052)		(56,052)
Other, net	5,429		1,821
Net cash provided by (used in) financing activities	1,110		(60,127)
Net decrease in cash, cash equivalents and restricted cash	(507)		(11,522)
Cash, cash equivalents and restricted cash at beginning of period	24,992		27,018
Cash, cash equivalents and restricted cash at end of period	$	24,485	$	15,496

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

7

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 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 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”), 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 four divisions that constitute our reportable segments:

•Offshore pipeline transportation, 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, marketing and selling activities, as well as soda ash production and processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and selling the related by-product, sodium hydrosulfide (or “NaHS,” commonly pronounced “nash”);

•Onshore facilities and transportation, which include terminaling, blending, storing, marketing and transporting 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

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”). 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”) 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, 2021 (our “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.

2. Recent Accounting Developments

Recent and Proposed Accounting Pronouncements

In March 2020, the 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 anticipated discontinuation of the 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 replacement of a 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 among other things, replaced our existing LIBOR rate based borrowings with the Term SOFR rate, which is based on the Secured Overnight Financing Rate (“SOFR”) borrowings. The impact to our senior secured credit facility and related interest expense upon transition to SOFR did not have a material impact on our Unaudited Condensed Consolidated Financial Statements for the three and nine months ended September 30, 2022. Refer to Note 9 for more details.

8

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 September 30, 2022 and 2021, respectively:

	Three Months Ended September 30, 2022
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	89,805	$	—	$	77,795	$	20,177	$	187,777
Product Sales	—		290,620		—		220,790		511,410
Refinery Services	—		22,061		—		—		22,061
	$	89,805	$	312,681	$	77,795	$	240,967	$	721,248

	Three Months Ended September 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities & Transportation		Consolidated
Fee-based revenues	$	69,479	$	—	$	48,716	$	26,603	$	144,798
Product Sales	—		210,997		—		136,372		347,369
Refinery Services	—		26,654		—		—		26,654
	$	69,479	$	237,651	$	48,716	$	162,975	$	518,821

The following tables reflect the disaggregation of our revenues by major category for the nine months ended September 30, 2022 and 2021, respectively:

	Nine Months Ended September 30, 2022
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	239,958	$	—	$	209,889	$	54,280	$	504,127
Product Sales	—		837,335		—		653,830		1,491,165
Refinery Services	—		79,628		—		—		79,628
	$	239,958	$	916,963	$	209,889	$	708,110	$	2,074,920

	Nine Months Ended September 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	207,084	$	—	$	136,673	$	69,173	$	412,930
Product Sales	—		628,209		—		428,940		1,057,149
Refinery Services	—		73,816		—		—		73,816
	$	207,084	$	702,025	$	136,673	$	498,113	$	1,543,895

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. During the

9

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

three and nine months ended September 30, 2021, we recorded immaterial amounts of revenue associated with prior periods of

approximately $10.7 million and $8.2 million, respectively, of which the majority was noncash.

Contract Assets and Liabilities

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

	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 September 30, 2022	—		16,662		35,602

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 September 30, 2022. We are 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.

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 2022	$	19,314	$	1,800
2023	67,941		7,200
2024	60,970		1,800
2025	64,292		—
2026	45,834		—
Thereafter	57,748		—
Total	$	316,099	$	10,800

4. Lease Accounting

Lessee Arrangements

We lease a variety of transportation equipment (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 and we recognize lease expense for these leases on a straight-line basis over the lease term.

Our “Right of Use Assets, 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” and “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 nine months ended September 30, 2022 and 2021, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, which is included in our marine transportation segment. Our lease revenues for this arrangement (inclusive of fixed and variable consideration) were $1.8 million and $4.1 million for the three months ended September 30, 2022 and 2021, respectively, and $10.5 million and $11.4 million for the nine months ended September 30, 2022 and 2021, respectively.

5. Inventories

The major components of inventories were as follows:

	September 30, 2022		December 31, 2021
Petroleum products	$	3,054	$	998
Crude oil	15,451		11,834
Caustic soda	11,636		5,690
NaHS	18,236		17,040
Raw materials - Alkali operations	6,672		7,599
Work-in-process - Alkali operations	8,299		7,496
Finished goods, net - Alkali operations	14,281		13,681
Materials and supplies, net - Alkali operations	15,278		13,620
Total	$	92,907	$	77,958

Inventories are valued at the lower of cost or net realizable value. As of September 30, 2022 and December 31, 2021, the net realizable value of inventories were below cost by $2.4 million and $2.0 million, respectively, which triggered a reduction of the value of inventory in our Consolidated Financial Statements by 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.

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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 consisted of the following:

	September 30, 2022		December 31, 2021
Crude oil and natural gas pipelines and related assets	$	2,840,829	$	2,839,443
Alkali facilities, machinery and equipment	688,569		670,880
Onshore facilities, machinery and equipment	269,249		269,245
Transportation equipment	22,032		21,106
Marine vessels	1,013,713		1,018,284
Land, buildings and improvements	229,202		227,540
Office equipment, furniture and fixtures	27,066		23,965
Construction in progress	599,802		350,137
Other	41,168		43,440
Fixed assets, at cost	5,731,630		5,464,040
Less: Accumulated depreciation	(1,711,306)		(1,551,855)
Net fixed assets	$	4,020,324	$	3,912,185

Mineral Leaseholds

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

	September 30, 2022		December 31, 2021
Mineral leaseholds	$	566,019	$	566,019
Less: Accumulated depletion	(19,844)		(17,014)
Mineral leaseholds, net of accumulated depletion	$	546,175	$	549,005

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Depreciation expense	$	70,328	$	63,482	$	206,111	$	190,332
Depletion expense	896		959		2,830		2,575

Asset Retirement Obligations

We record asset retirement obligations (“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, 2021:

ARO liability balance, December 31, 2021	$	220,906
Accretion expense	10,175
Changes in estimate	3,189
Settlements	(12,267)
ARO liability balance, September 30, 2022	$	222,003

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

At September 30, 2022 and December 31, 2021, $28.8 million and $36.3 million are included as current in “Accrued liabilities” on our Unaudited Condensed Consolidated Balance Sheets, respectively. The remainder of the ARO liability as of September 30, 2022 and December 31, 2021 is included in “Other long-term liabilities” on our Unaudited Condensed Consolidated Balance Sheets.

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

Remainder of	2022	$	2,909
	2023	$	10,640
	2024	$	9,827
	2025	$	10,532
	2026	$	8,281

Certain of our unconsolidated affiliates have AROs recorded at September 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 September 30, 2022 and December 31, 2021, the unamortized excess cost amounts totaled $309.2 million and $319.9 million, respectively. We amortize the differences in carrying value as 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 September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Genesis’ share of operating earnings	$	16,802	$	14,174	$	50,950	$	56,801
Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)		(3,873)		(10,698)		(11,618)
Net equity in earnings	$	13,236	$	10,301	$	40,252	$	45,183
Distributions received(1)	$	18,483	$	17,443	$	56,233	$	68,873

(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):

	September 30, 2022		December 31, 2021
BALANCE SHEETS DATA:
Assets
Current assets	$	27,448	$	17,827
Fixed assets, net	150,416		160,379
Other assets	11,958		6,186
Total assets	$	189,822	$	184,392
Liabilities and equity
Current liabilities	$	12,667	$	7,668
Other liabilities	234,401		231,970
Equity (Deficit)	(57,246)		(55,246)
Total liabilities and equity	$	189,822	$	184,392

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
STATEMENTS OF OPERATIONS DATA:
Revenues	$	38,322	$	27,262	$	104,891	$	103,432
Operating income	$	27,731	$	18,762	$	75,540	$	75,559
Net income	$	25,502	$	17,718	$	70,850	$	72,473

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 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:

	September 30, 2022						December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Marine contract intangibles	$	800	$	634	$	166	$	800	$	607	$	193
Offshore pipeline contract intangibles	158,101		59,635		98,466		158,101		53,394		104,707
Other	45,811		17,242		28,569		37,933		15,770		22,163
Total	$	204,712	$	77,511	$	127,201	$	196,834	$	69,771	$	127,063

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Amortization of intangible assets	$	2,575	$	2,575	$	7,740	$	7,755

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

Remainder of	2022	$	3,132
	2023	$	12,302
	2024	$	11,937
	2025	$	11,712
	2026	$	11,412

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

9. Debt

Our obligations under debt arrangements consisted of the following:

	September 30, 2022						December 31, 2021
	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)	$	120,200	$	—	$	120,200	$	49,000	$	—	$	49,000
5.625% senior unsecured notes due 2024	341,135		1,464		339,671		341,135		2,106		339,029
6.500% senior unsecured notes due 2025	534,834		3,562		531,272		534,834		4,452		530,382
6.250% senior unsecured notes due 2026	339,310		2,664		336,646		359,799		3,410		356,389
8.000% senior unsecured notes due 2027	981,245		5,325		975,920		1,000,000		6,592		993,408
7.750% senior unsecured notes due 2028	679,360		7,995		671,365		720,975		9,678		711,297
5.875% Alkali senior secured notes due 2042	425,000		22,746		402,254		—		—		—
Total long-term debt	$	3,421,084	$	43,756	$	3,377,328	$	3,005,743	$	26,238	$	2,979,505

(1)    Unamortized debt issuance costs associated with our Revolving Loan, as defined below (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were $3.1 million and $4.7 million as of September 30, 2022 and December 31, 2021, respectively.

Senior Secured Credit Facility

On April 8, 2021, we entered into the Fifth Amended and Restated Credit Agreement (the “credit agreement”) to replace our Fourth Amended and Restated Credit 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”) and a term loan facility of $300 million (the “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 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.

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 September 30, 2022, the key terms for rates under our Revolving Loan (which are dependent on our leverage ratio as defined in the credit agreement amendment) are as follows:

•The interest rate on borrowings may be based on an alternate base rate or Term SOFR, at our option. Interest on alternate base rate loans is equal to the sum of (a) the 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% and (iii) the Adjusted Term SOFR (as defined in our credit agreement amendment) for a one-month tenor in effect on such day plus 1% and (b) the applicable margin. The Adjusted Term SOFR is equal to the sum of (a) the Term SOFR rate (as defined in our credit agreement amendment) for such period plus (b) the Term SOFR Adjustment of 0.1% plus (c) the applicable margin. The applicable margin varies from 2.25% to 3.75% on 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 September 30, 2022, the applicable margins on our borrowings were 2.00% for alternate base rate borrowings and 3.00% for Term SOFR borrowings based on our leverage ratio.

•Letter of credit fee rates range from 2.25% to 3.75% based on our leverage ratio as computed under the credit agreement and can fluctuate quarterly. At September 30, 2022, our letter of credit rate was 3.00%.

•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 September 30, 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

At September 30, 2022, we had $120.2 million outstanding under our Revolving Loan, with $11.3 million of the borrowed amount designated as a loan under the inventory sublimit. Our credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which $4.5 million was outstanding at September 30, 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 September 30, 2022 was $525.3 million, subject to compliance with covenants. Our credit agreement does not include a “borrowing base” limitation except with respect to our inventory loans.

Alkali Senior Secured Notes Issuance and Related Transactions

On May 17, 2022, Genesis Energy, L.P., through its newly created wholly-owned unrestricted subsidiary, GA ORRI, LLC (“GA ORRI”), issued $425 million principal amount of our 5.875% senior secured notes due 2042 (the “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 on the last day of each quarter with the initial interest payment made 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 $49.9 million are due within the next five years, with the remaining quarterly principal repayments due thereafter through March 31, 2042. We are required to maintain a certain level of cash in a liquidity reserve account (owned by GA ORRI) to be held as collateral for future interest and principal payments as calculated and described in the agreement governing the Alkali senior secured notes. As of September 30, 2022 our liquidity reserve account had a balance of $18.6 million, which is classified as “Restricted cash” on the Unaudited Condensed Consolidated Balance Sheet. The issuance generated net proceeds of $408 million, net of the issuance discount of $17 million. We used a portion of the net proceeds 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 under our credit agreement as well as fund our liquidity reserve account.

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 credit agreement. We also designated GA ORRI and GA ORRI Holdings as unrestricted subsidiaries under the indentures governing our senior unsecured notes. On May 17, we also reclassified the subsidiaries originally held by our Alkali Business as restricted subsidiaries under our credit agreement and under the indentures governing our 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”). 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”) (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 debt issuance costs, which is recorded in “Other income (expense)” in our Unaudited Condensed Consolidated Statements of Operations for the nine months ended September 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 credit agreement.

During 2022, we repurchased certain of our senior unsecured notes on the open market and recorded cancellation of debt income of $3.9 million and $8.6 million for the three and nine months ended September 30, 2022, respectively. These are recorded within “Other income (expense)” in our Unaudited Consolidated Statements of Operations.

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 current and future 100% owned domestic subsidiaries (the “Guarantor Subsidiaries”), except GA ORRI and GA ORRI Holdings, and certain other subsidiaries. The non-guarantor subsidiaries are indirectly owned by Genesis Crude Oil, L.P., a

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Guarantor Subsidiary. The Guarantor Subsidiaries largely own the assets, other than the ORRI Interests, that we use to operate our 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.

10. Partners’ Capital, Mezzanine Capital and Distributions

At September 30, 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 September 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 2021 and 2022:

Distribution For	Date Paid		Per Unit Amount		Total Amount
2021
1st Quarter	May 14, 2021		$	0.15	$	18,387
2nd Quarter	August 13, 2021		$	0.15	$	18,387
3rd Quarter	November 12, 2021		$	0.15	$	18,387
4th Quarter	February 14, 2022		$	0.15	$	18,387
2022
1st Quarter	May 13, 2022		$	0.15	$	18,387
2nd Quarter	August 12, 2022		$	0.15	$	18,387
3rd Quarter	November 14, 2022	(1)	$	0.15	$	18,387

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

Class A Convertible Preferred Units

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. We initially recognized our Class A Convertible Preferred Units at their issuance date fair value, net of issuance costs, as they were not redeemable and we did not have plans or expect any events that constitute a change of control in our partnership agreement. Additionally, our Class A Convertible Preferred Units contains a distribution Rate Reset Election (as defined in Note 15), which was elected by the holders of the Class A Convertible Preferred Units on September 29, 2022 (the “election date”). From the date of issuance through the election date, this distribution rate reset was bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period in “Other long-term liabilities” in our Unaudited Condensed Consolidated Balance Sheets. As of the election date, the feature within the Class A Convertible Preferred Units that required bifurcation no longer existed and we have adjusted the carrying value of the Class A Convertible Preferred Units to include the fair value of the previously bifurcated amount at the election date. Refer to Note 15 and Note 16 for additional discussion.

As of September 30, 2022, we will not be required to further 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

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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.

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 $56.1 million for the three and nine months ended September 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		$	0.7374	$	18,684
3rd Quarter	November 14, 2022	(1)	$	0.7374	$	18,684

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

As a result of the one-time Rate Reset Election made by the holders of the Class A Convertible Preferred Units on the election date, the annual distribution rate for the Class A Convertible Preferred Units increased from 8.75% to 11.24%, applicable for future quarterly distributions declared and payable, beginning with the quarter ended December 31, 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”) and a Securities Purchase Agreement (the “Securities Purchase Agreement”) whereby certain investment fund entities affiliated with Blackstone Alternative Credit Advisors LP, formerly known as “GSO Capital Partners LP” (collectively “BXC”) purchased $55.0 million (or 55,000 Alkali Holdings preferred units) and committed to purchase up to $350.0 million of Alkali Holdings preferred units, 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 utilized the net proceeds received from the preferred units to fund a portion of the anticipated cost of expansion of the Granger facility (the “Granger Optimization Project” or “GOP”).

On April 14, 2020, we entered into an amendment to our agreements with BXC to, among other things, extend the construction timeline of the GOP by one year, which we currently anticipate completing in the third quarter of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to 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 BXC was increased to, subject to compliance with the covenants contained in the agreements with BXC, up to $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 September 30, 2022, there were no Alkali Holdings preferred units outstanding.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Accounting for Redeemable Noncontrolling Interests

Classification

Prior to the Redemption Date, the Alkali Holdings preferred units issued and outstanding 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.

    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 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 was the IRR measure accreted using the effective interest method to the redemption value as of 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 Income Attributable to Genesis Energy, L.P. for the nine months ended September 30, 2022 includes $30.4 million of adjustments, of which $10.0 million was allocated to the paid-in-kind (“PIK”) distributions on the outstanding Alkali Holdings preferred units,$1.9 million, was attributable to redemption accretion value adjustments, and $18.5 million was attributable to 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 nine months ended September 30, 2021 includes $7.1 million and $17.7 million of adjustments, respectively, of which $5.9 million and $14.9 million, respectively, was allocated to the PIK distributions and $1.2 million and $2.8 million, respectively, was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended September 30, 2022 in-kind to our Alkali Holdings preferred unitholders.

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

Balance as of December 31, 2021	$	259,568
Issuance of preferred units, net of issuance costs(1)	5,249
PIK distribution	9,993
Redemption accretion	1,908
Tax distributions(1)	(6,631)
Adjustment to Base Preferred Return Amount	18,542
Redemption of preferred units on May 17, 2022	(288,629)
Balance as of September 30, 2022	$	—

(1)During the nine months ended September 30, 2022, we issued 5,356 Alkali Holdings preferred units to BXC to satisfy the Company’s obligation to pay tax distributions.

Noncontrolling Interests

On November 17, 2021, we, 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 its associated assets. We also own an 80% membership interest in Independence Hub, LLC. On April 29, 2022, we entered into an agreement to sell the Independence Hub platform to a producer group in the Gulf of Mexico for gross proceeds of $40.0 million, of which $8.0 million, or 20%, was attributable and was paid to our noncontrolling interest holders. For the nine months ended September 30, 2022, we recognized a gain of $40.0 million recorded in “Gain on sale of asset” on the Unaudited Condensed Consolidated Statement of Operations, of which $8.0 million, or 20%, is attributable to our noncontrolling interest holders, as the 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

11. Net Loss Per Common Unit

Basic net income (loss) per common unit is computed by dividing 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, 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 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 nine months ended September 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 income (loss) attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net loss per common unit (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
Net loss attributable to common unitholders	$	(15,299)	$	(39,583)	$	(22,570)	$	(152,857)
Weighted average outstanding units	122,579		122,579		122,579		122,579
Basic and diluted net loss per common unit	$	(0.12)	$	(0.32)	$	(0.18)	$	(1.25)

12. Business Segment Information

We currently manage our businesses through four 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 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 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 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. 

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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
Three Months Ended September 30, 2022
Segment Margin(1)	$	91,402	$	80,067	$	9,442	$	15,279	$	196,190
Capital expenditures(2)	$	86,893	$	49,452	$	848	$	14,575	$	151,768
Revenues:
External customers	$	89,805	$	315,334	$	238,483	$	77,626	$	721,248
Intersegment(3)	—		(2,653)		2,484		169		—
Total revenues of reportable segments	$	89,805	$	312,681	$	240,967	$	77,795	$	721,248
Three Months Ended September 30, 2021
Segment Margin(1)	$	76,045	$	39,649	$	29,145	$	9,023	$	153,862
Capital expenditures(2)	$	3,819	$	67,583	$	929	$	6,886	$	79,217
Revenues:
External customers	$	69,479	$	240,048	$	161,296	$	47,998	$	518,821
Intersegment(3)	—		(2,397)		1,679		718		—
Total revenues of reportable segments	$	69,479	$	237,651	$	162,975	$	48,716	$	518,821
Nine Months Ended September 30, 2022
Segment Margin(1)	$	281,286	$	219,143	$	27,496	$	44,989	$	572,914
Capital expenditures(2)	$	166,703	$	114,698	$	3,365	$	28,704	$	313,470
Revenues:
External customers	$	239,958	$	924,534	$	700,909	$	209,519	$	2,074,920
Intersegment(3)	—		(7,571)		7,201		370		—
Total revenues of reportable segments	$	239,958	$	916,963	$	708,110	$	209,889	$	2,074,920
Nine Months Ended September 30, 2021
Segment Margin(1)	$	243,420	$	121,563	$	72,512	$	24,600	$	462,095
Capital expenditures(2)	$	34,768	$	158,181	$	4,515	$	29,757	$	227,221
Revenues:
External customers	$	207,084	$	708,612	$	493,852	$	134,347	$	1,543,895
Intersegment(3)	—		(6,587)		4,261		2,326		—
Total revenues of reportable segments	$	207,084	$	702,025	$	498,113	$	136,673	$	1,543,895

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

(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.

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

Total assets by reportable segment were as follows:

	September 30, 2022		December 31, 2021
Offshore pipeline transportation	$	2,214,924	$	2,103,140
Sodium minerals and sulfur services	2,230,163		2,132,588
Onshore facilities and transportation	974,464		923,064
Marine transportation	692,303		703,030
Other assets	57,685		43,979
Total consolidated assets	$	6,169,539	$	5,905,801

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Corporate general and administrative expenses	18,132		14,878		54,958		38,389
Depreciation, depletion, amortization and accretion	76,301		69,665		225,526		208,346
Interest expense	57,710		59,940		168,773		176,938
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income(1)	5,247		7,142		15,981		23,690
Other non-cash items(2)	24,636		(2,526)		12,157		30,601
Distribution from unrestricted subsidiaries not included in income(3)	—		17,500		32,000		52,500
Cancellation of debt income(4)	(3,881)		—		(8,618)		—
Loss on extinguishment of debt(5)	293		—		794		1,627
Differences in timing of cash receipts for certain contractual arrangements(6)	13,775		657		38,482		7,402
Change in provision for leased items no longer in use	(68)		—		(599)		598
Redeemable noncontrolling interest redemption value adjustments(7)	—		7,082		30,443		17,639
Gain on sale of asset, net to our ownership interest(8)	—		—		(32,000)		—
Income tax expense	660		423		1,535		1,170
Total Segment Margin	$	196,190	$	153,862	$	572,914	$	462,095

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

(2)The three and nine months ended September 30, 2022 include an unrealized loss of $25.0 million and $18.6 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and nine months ended September 30, 2021 include an unrealized gain of $1.7 million and an unrealized loss of $31.0 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units.

(3)The nine months ended September 30, 2022 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 three and nine months ended September 30, 2021 include $17.5 million and $52.5 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 agreement.

(4)The three and nine months ended September 30, 2022 includes income associated with the repurchase and extinguishment of certain of our senior unsecured notes on the open market of $3.9 million and $8.6 million, respectively.

(5)The three and nine months ended September 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 nine months ended September 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.

(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.

(7)Includes PIK distributions and accretion on the redemption feature attributable to each period, and valuation adjustments to the redemption feature as the associated preferred units were redeemed during the second quarter of 2022. Refer to Note 10 for details.

(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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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

13. Transactions with Related Parties

The transactions with related parties were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues:
Revenues from services and fees to Poseidon(1)	$	3,854	$	3,193	$	10,952	$	10,221
Revenues from product sales to ANSAC	109,046		61,651		294,556		200,935
Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	495	$	495
Charges for services from Poseidon(1)	268		242		777		720
Charges for services from ANSAC	2,596		400		5,781		1,097

(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 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 nine months ended September 30, 2022 include $2.4 million and $7.3 million, respectively, of fees we earned through the provision of services under that agreement. Our revenues for the three and nine months ended September 30, 2021 include $2.4 million and $7.1 million, respectively, of fees we earned through the provision of services under that agreement. At September 30, 2022 and December 31, 2021, Poseidon owed us $2.0 million and $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”), 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 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 September 30, 2022, such amount is not material to us.

Net Sales to ANSAC were $109.0 million and $294.6 million, respectively, during the three and nine months ended September 30, 2022, and were $61.7 million and $200.9 million, respectively, during the three and nine months ended September 30, 2021. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $2.6 million and $5.8 million, respectively, during the three and nine months ended September 30, 2022, and were $0.4 million and $1.1 million, respectively, during the three and nine months ended September 30, 2021.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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

	September 30,		December 31,
	2022		2021
Accounts receivable - trade, net:
ANSAC	$	103,582	$	64,799
Accounts payable - trade:
ANSAC	$	2,596	$	116

14. Supplemental Cash Flow Information

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

	Nine Months Ended September 30,
	2022		2021
(Increase) decrease in:
Accounts receivable	$	(170,635)	$	15,487
Inventories	(12,677)		11,108
Deferred charges	47,191		20,362
Other current assets	(4,717)		(10,335)
Increase (decrease) in:
Accounts payable	109,687		(50,361)
Accrued liabilities	(17,425)		20,196
Net changes in components of operating assets and liabilities	$	(48,576)	$	6,457

Payments of interest and commitment fees were $189.2 million and $154.4 million for the nine months ended September 30, 2022 and September 30, 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 and July during 2022. The first interest payment made on our 2027 Notes was in July 2021.

We capitalized interest of $11.2 million and $2.3 million during the nine months ended September 30, 2022 and September 30, 2021, respectively. The increase in capitalized interest is due to our growth capital expenditures associated with our GOP (Note 10) and our offshore growth capital projects.

At September 30, 2022 and September 30, 2021, we had incurred liabilities for fixed and intangible asset additions totaling $67.6 million and $44.9 million, respectively, that had not been paid at the end of the 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 amounts as of September 30, 2022 primarily relate to the capital expenditures associated with our GOP (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 (exchange-traded futures, options and 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; therefore, we do not designate derivative contracts utilized to limit our price risk related to 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

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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

Additionally, we 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, 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 natural gas derivative contracts as increases or decreases within “Sodium minerals and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations.

At September 30, 2022, we 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)	104		—
Weighted average contract price per Bbl	$	88.81	$	—
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 Bbls)	102		96
Weighted average contract price per Bbl	$	85.02	$	84.56
Natural gas swaps:
Contract volumes (10,000 MMBtu)	—		367
Weighted average price differential per MMBtu	$	—	$	(0.30)
Natural gas futures:
Contract volumes (10,000 MMBtu)	66		433
Weighted average contract price per MMBtu	$	7.50	$	5.26
Petroleum products (#6 fuel oil) futures:
Contract volumes (1,000 Bbls)	120		70
Weighted average contract price per Bbl	$	61.81	$	60.99
Natural gas options:
Contract volumes (10,000 MMBtu)	109		20
Weighted average premium received/paid	$	0.59	$	0.07

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

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in the cash margin balance required to maintain our exchange-traded derivative contracts also affect cash flows from operating activities.

The following tables reflect the estimated fair value position of our derivatives at September 30, 2022 and December 31, 2021:

Fair Value of Derivative Assets and Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2022		December 31, 2021
Asset Derivatives:
Natural Gas Swap (undesignated hedge)	Current Assets - Other	221		1,867
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized assets	Current Assets - Other	$	3,688	$	310
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(1,622)		(310)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	2,066	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized assets	Current Assets - Other	$	1,599	$	49
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(557)		(49)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	1,042	$	—
Liability Derivatives:
Preferred Distribution Rate Reset Election(2)	Other long-term liabilities	—		(83,210)
Natural Gas Swap (undesignated hedge)	Current Liabilities -Accrued Liabilities	(808)		(608)
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(1,622)	$	(2,380)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	1,622		2,380
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets		$	—	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(557)	$	(209)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	557		209
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 Assets - Other”.

(2)Refer to Note 10, Note 16 and below 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 our cash 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 September 30, 2022, we had a net broker receivable of approximately $5.8 million (consisting of initial margin of $5.3 million increased by $0.5 million variation margin).  As of December 31, 2021, we had a net broker receivable of

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

approximately $2.9 million (consisting of initial margin of $2.1 million increased by $0.8 million of variation margin).  At September 30, 2022 and December 31, 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. 

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 distribution amount (a “Rate Reset 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 Sheets. Corresponding changes in fair value are recognized in “Other income (expense)” in our Unaudited Condensed Consolidated Statement of Operations.

On the election date, the holders of the Class A Convertible Preferred Units elected to reset the rate to 11.24%, the sum of the three-month LIBOR of 3.74% plus 750 basis points. The fair value of this embedded derivative at the time of election was a liability of $101.8 million. As of the election date, the feature within the Class A Convertible Preferred Units that required bifurcation no longer existed and we have adjusted the carrying value of the Class A Convertible Preferred Units to include the fair value of the previously bifurcated amount at the election date. 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
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	2,085	$	(285)	$	1,549	$	(7,745)
Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	7,138		(171)		15,418		(5,871)
Total commodity derivatives		$	9,223	$	(456)	$	16,967	$	(13,616)
Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	(489)	$	(55)	$	(2,181)	$	(92)
Preferred Distribution Rate Reset Election	Other income (expense)	$	(24,977)	$	1,740	$	(18,584)	$	(31,042)

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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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.

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 September 30, 2022 and December 31, 2021. 

	September 30, 2022						December 31, 2021
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Commodity derivatives:
Assets	$	5,287	$	221	$	—	$	359	$	1,867	$	—
Liabilities	$	(2,179)	$	(808)	$	—	$	(2,589)	$	(608)	$	—
Preferred Distribution Rate Reset Election	$	—	$	—	$	—	$	—	$	—	$	(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:

Balance as of December 31, 2021	$	(83,210)
Net loss for the period included in earnings	(18,584)
Reclassification to Mezzanine Equity	101,794
Balance as of September 30, 2022	$	—

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 September 30, 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 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 September 29, 2022, which represents the final valuation date of the embedded derivative due to the Rate Reset Election. Due primarily to the election of the rate reset increasing the annual distribution rate from 8.75% to 11.24%, we recorded an unrealized loss of $25.0 million and $18.6 million for the three and nine months ended September 30, 2022, respectively. Due to an increase in our discount yield compared to the preceding quarter, we recorded an unrealized gain of $1.7 million for the three months ended September 30, 2021; however, an overall decrease in our discount yield compared to December 31, 2020 resulted in an unrealized loss of $31.0 million for the nine months ended September 30, 2021. These effects are all recorded within “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 September 30, 2022 our senior unsecured notes had a carrying value of approximately $2.9 billion and a fair value of approximately $2.6 billion compared to a carrying value and fair value of approximately $3.0 billion at December 31, 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 $3.4 million during the three months ended September 30, 2022 (the “2022 Quarter”) compared to Net Loss Attributable to Genesis Energy, L.P. of $20.9 million during the three months ended September 30, 2021 (the “2021 Quarter”).

Net Income Attributable to Genesis Energy, L.P. in the 2022 Quarter was impacted primarily by: (i) an increase in our Segment Margin of $42.3 million (see “Results of Operations” below for additional details on the results of our operating segments); (ii) a decrease in income attributable to our redeemable noncontrolling interests by $7.1 million as the associated Alkali Holdings preferred units were redeemed during the second quarter of 2022; (iii) cancellation of debt income recognized during the 2022 Quarter of $3.9 million associated with the open market repurchase and extinguishment of certain of our senior unsecured notes recorded within “Other income (expense)”; and (iv) an increase in equity in earnings of equity investees of $2.9 million primarily due to increased volumes on our 64% owned Poseidon oil pipeline, which is our most significant equity method investment.

These increases were partially offset by (i) an unrealized (non-cash) loss from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units of $25.0 million in the 2022 Quarter compared to an unrealized (non-cash) gain of $1.7 million during the 2021 Quarter recorded within “Other income (expense)”, and (ii) an increase in depreciation, depletion, and amortization expense of $6.8 million (see “Results of Operations” below for additional details.)

Cash flow from operating activities was $94.3 million for the 2022 Quarter compared to $54.2 million for the 2021 Quarter. The increase in cash flow from operating activities is primarily attributable to the increase in our Segment Margin. A more detailed discussion of our segment results and other costs are included below in “Results of Operations”.

Available Cash before Reserves (as defined below in “Non-GAAP Financial Measures”) to our common unitholders was $92.6 million for the 2022 Quarter, an increase of $44.4 million, or 92%, from the 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 Financial Measures”) was $196.2 million for the 2022 Quarter, an increase of $42.3 million, or 28%, from the 2021 Quarter. A more detailed discussion of our segment results and other costs are included below in “Results of Operations”.

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

Distribution to Unitholders

On August 12, 2022, we paid a distribution of $0.15 per unit related to the second quarter of 2022.

In October 2022, we declared our quarterly distribution to our common unitholders of $0.15 per unit related to the 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 November 14, 2022 to unitholders of record at the close of business on October 31, 2022.

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Covid-19, Ukraine War and Market Update

Since March 2020, and throughout the last two years, global markets and commodity prices have been extremely volatile due to the impacts from the Covid-19 pandemic, with further impacts on volatility caused by the war in Ukraine that began in February 2022. While we have seen continued recovery in commodity prices since the beginning of the pandemic, there is still an element of volatility that we expect to continue at least for the near-term and possibly longer, due to the uncertainty of the pandemic, the war in Ukraine and the result of any economic recession or depression that has occurred or may occur in the future. This volatility could negatively impact future prices for oil, natural gas, petroleum products and industrial products.

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 could cause our estimates to differ significantly from actual results, including with respect to the duration and severity of the Covid-19 pandemic, the war in Ukraine, the result of any economic recession or depression that has occurred or may occur in the future as a result or as it relates to changes in governmental policies aimed at addressing inflation which could cause fluctuations in global economic conditions, including capital and credit markets. We will continue to monitor the current market 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.

Although 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 deleveraging our balance sheet as further explained in “Liquidity and Capital Resources”.

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Results of Operations

Revenues and Costs and Expenses

Our revenues for the 2022 Quarter increased $202.4 million, or 39%, from the 2021 Quarter and our total costs and expenses as presented on the Unaudited Condensed Consolidated Statements of Operations increased $161.8 million, or 33%, between the two periods. The increase in our operating income during the 2022 Quarter is primarily driven by higher export pricing and volumes and corresponding revenues in our Alkali Business, which is included within our sodium mineral and sulfur services segment, higher volumes and revenues in our offshore pipeline transportation segment, and increased utilization and day rates in our marine transportation segment (see further discussion below on our individual operating segments). These increases are partially offset by higher depreciation, depletion, and amortization expense and general and administrative costs during 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. 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”) increased to $93.06 per barrel in the 2022 Quarter, as compared to $70.56 per barrel in the 2021 Quarter. 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 (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 volumes sold. We sell our products into a global market to an industry-diverse and worldwide customer base. Our selling prices are primarily driven by global supply and demand and 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 year or periodically throughout the current year (often quarterly), 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 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 2022 Quarter as noted above, we had positive effects to our revenues (with a lesser impact to costs) relative to the 2021 Quarter due to favorable ANSAC pricing on our export tons and an increase in volumes. 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 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 contracted for approximately 90% of the 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 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

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volatile commodity price environments. Given these facts, we do not expect changes in commodity prices to impact our 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 September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Offshore pipeline transportation	$	91,402	$	76,045	$	281,286	$	243,420
Sodium minerals and sulfur services	80,067		39,649		219,143		121,563
Onshore facilities and transportation	9,442		29,145		27,496		72,512
Marine transportation	15,279		9,023		44,989		24,600
Total Segment Margin	$	196,190	$	153,862	$	572,914	$	462,095

We define Segment Margin as revenues less product costs, operating expenses and segment general and administrative expenses (all of which are net of the effects of our noncontrolling interest holders), plus or minus applicable Select 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 Financial Measures” for further discussion surrounding total Segment Margin.

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net Income (Loss) Attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Corporate general and administrative expenses	18,132		14,878		54,958		38,389
Depreciation, depletion, amortization and accretion	76,301		69,665		225,526		208,346
Interest expense	57,710		59,940		168,773		176,938
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income(1)	5,247		7,142		15,981		23,690
Other non-cash items(2)	24,636		(2,526)		12,157		30,601
Distributions from unrestricted subsidiaries not included in income(3)	—		17,500		32,000		52,500
Change in provision for leased items no longer in use	(68)		—		(599)		598
Differences in timing of cash receipts for certain contractual arrangements(4)	13,775		657		38,482		7,402
Cancellation of debt income(5)	(3,881)		—		(8,618)		—
Loss on debt extinguishment(6)	293		—		794		1,627
Redeemable noncontrolling interest redemption value adjustments(7)	—		7,082		30,443		17,639
Gain on sale of asset, net to our ownership interest(8)	—		—		(32,000)		—
Income tax expense	660		423		1,535		1,170
Total Segment Margin	$	196,190	$	153,862	$	572,914	$	462,095

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

(2)The three and nine months ended September 30, 2022 include unrealized losses of $25.0 million and $18.6 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and nine months ended September 30, 2021 include an unrealized gain of $1.7 million and an unrealized loss of $31.0 million, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units.

(3)The nine months ended September 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 nine months ended September 30, 2021 include $17.5 million and $52.5 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 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 nine months ended September 30, 2022 include income associated with the repurchase and extinguishment of certain of our senior unsecured notes on the open market of $3.9 million and $8.6 million, respectively.

(6)The three and nine months ended September 30, 2022 include the write-off of the unamortized issuance costs associated with the senior unsecured notes that we repurchased and extinguished during the period. The nine months ended September 30, 2021 include 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.

(7)Includes PIK distributions and accretion on the redemption feature attributable to each period, and valuation adjustments to the redemption feature as the associated Alkali Holdings preferred units were redeemed during the second quarter of 2022.

(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 September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Offshore crude oil pipeline revenue, net to our ownership interest and excluding non-cash revenues	$	79,638	$	68,342	$	216,562	$	201,157
Offshore natural gas pipeline revenue, excluding non-cash revenues	13,141		8,878		35,649		29,842
Offshore pipeline operating costs, net to our ownership interest and excluding non-cash expenses	(19,860)		(18,218)		(57,383)		(55,552)
Distributions from unrestricted subsidiaries(1)	—		—		32,000		—
Distributions from equity investments(2)	18,483		17,043		54,458		67,973
Offshore pipeline transportation Segment Margin	$	91,402	$	76,045	$	281,286	$	243,420
Volumetric Data 100% basis:
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS	197,583		211,809		198,067		178,083
Poseidon	282,583		208,593		262,222		270,641
Odyssey	88,112		94,171		95,160		119,100
GOPL(3)	7,578		7,169		7,047		7,532
Total crude oil offshore pipelines	575,856		521,742		562,496		575,356
Natural gas transportation volumes (MMBtus/day)	358,618		317,025		338,598		329,908
Volumetric Data net to our ownership interest(4):
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS(5)	126,453		211,809		126,763		178,083
Poseidon	180,853		133,500		167,822		173,210
Odyssey	25,552		27,310		27,596		34,539
GOPL(3)	7,578		7,169		7,047		7,532
Total crude oil offshore pipelines	340,436		379,788		329,228		393,364
Natural gas transportation volumes (MMBtus/day)	114,671		100,418		108,673		103,863

(1)Offshore pipeline transportation Segment Margin for the nine months ended September 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 2022 and 2021, respectively.     

(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.

(5)On November 17, 2021, we divested a 36% minority interest in our CHOPS pipeline. The volumes for the three and nine months ended September 30, 2022 represent our 64% net ownership and the volumes presented for the three and nine months ended September 30, 2021 represent our 100% ownership during that period.

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Offshore pipeline transportation Segment Margin for the 2022 Quarter increased $15.4 million, or 20%, from the 2021 Quarter due to increased crude oil and natural gas volumes (on a 100% basis) and associated revenues during the 2022 Quarter

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primarily as a result of first oil being achieved on April 12, 2022 at the King’s Quay floating production system. The King’s Quay floating production system, which is supporting the Khaleesi, Mormont and Samurai field developments, is life-of-lease dedicated to our 100% owned crude oil and natural gas lateral pipelines and further downstream to our 64% owned Poseidon and CHOPS crude oil systems or our 25.67% owned Nautilus natural gas system for ultimate delivery to shore. During the 2022 Quarter, the volumes at King’s Quay increased significantly from the second quarter of 2022 as the operator continued to bring additional wells online and ramp up activity. In addition to this, we have contractual minimum volume commitments (“MVCs”) that began in 2022 associated with the Argos floating production system (which supports the Mad Dog 2 development) that are included in our reported Segment Margin during the 2022 Quarter. Argos is anticipated to have first oil in the coming months. Lastly, the 2021 Quarter had more downtime compared to the 2022 Quarter as a result of Hurricane Ida. These increases more than offset the effects to reported Segment Margin from our decrease in ownership of CHOPS, as we sold a 36% minority interest on November 17, 2021.

Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Offshore pipeline transportation Segment Margin for the first nine months of 2022 increased $37.9 million, or 16%, from the first nine months of 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 succeeded by a ramp up in production throughout the 2022 Quarter, as well as our MVCs associated with Argos recognized during the period. These increases were partially offset by an increased level of operational downtime during 2022, specifically in the first quarter, that was primarily a result of unplanned operational maintenance associated with one of our lateral pipelines that also impacted volumes on our 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 36% minority interest on November 17, 2021.

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Sodium Minerals and Sulfur Services Segment

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Volumes sold:
NaHS volumes (Dry short tons “DST”)	29,441		27,873		97,243		84,727
Soda Ash volumes (short tons sold)	776,284		686,851		2,293,213		2,221,803
NaOH (caustic soda) volumes (DST)	23,186		22,456		65,983		63,842
Revenues (in thousands):
NaHS revenues, excluding non-cash revenues	$	42,821	$	32,631	$	136,633	$	92,901
NaOH (caustic soda) revenues	19,774		11,572		50,451		29,778
Revenues associated with Alkali Business	228,414		167,789		651,105		508,892
Other revenues	2,263		1,402		6,716		3,225
Total external segment revenues, excluding non-cash revenues(1)	$	293,272	$	213,394	$	844,905	$	634,796
Segment Margin (in thousands)	$	80,067	$	39,649	$	219,143	$	121,563
Average index price for NaOH per DST(2)	$	1,177	$	825	$	1,075	$	743

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

(2)Source: IHS Chemical.

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Sodium minerals and sulfur services Segment Margin for the 2022 Quarter increased $40.4 million, or 102%, from the 2021 Quarter primarily due to higher export pricing and increased volumes in our Alkali Business as well as increased volumes and pricing in our refinery services business. In our Alkali Business, we have continued to see strong demand improvement and growth as a result of the global economic recovery and the continued use of soda ash in the production of 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 improvement, combined with flat or even slightly declining supply of soda ash in the near term, has continued to tighten the overall supply and demand balance and created a higher price environment for our tons and increased contribution to Segment Margin during the 2022 Quarter. We expect to continue to see this favorable price environment for the remainder of 2022. To take advantage of the existing market conditions, we made the decision and 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 2023 in advance of the completion of the 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 had an increase in NaHS sales volumes in the 2022 Quarter due to an increase in demand from our mining customers, primarily in South America, as a result of the continued global economic recovery and the use of 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 continue benefiting from favorable index pricing. Lastly, our largest host refinery began its scheduled major turnaround during the 2022 Quarter. As a result, we made the decision to simultaneously take an extended outage at our sulfur removal unit to conduct a variety of scheduled and long-term maintenance items during this period. While we did not see any impact to Segment Margin in the 2022 Quarter, due to our ability to build inventory to a level adequate to meet our customer demands prior to the start of the turnaround, we do expect a temporary reduction in supply during the fourth quarter of 2022 as our host refinery works back up to normal operations as well as an increase in our costs due to our internal maintenance.

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Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Sodium minerals and sulfur services Segment Margin for the first nine months of 2022 increased $97.6 million, or 80%, from the first nine months of 2021 primarily due to higher export pricing and sales volumes in our Alkali business and increased volumes and pricing in our refinery services business. In our Alkali Business, we have continued to see strong demand improvement and 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, combined with flat or even slightly declining supply of 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 2022. In our refinery services business, we had an increase in NaHS sales volumes and the corresponding pricing of these sales volumes in 2022 due to an increase in demand from our mining customers as a result of the continued global economic recovery and the use of NaHS in products, such as copper, that are a key part of the anticipated energy transition.

Onshore Facilities and Transportation Segment

Our onshore facilities and transportation segment utilizes an integrated set of pipelines and terminals, trucks 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 U.S. Gulf Coast crude oil market. In addition, we utilize our trucking fleet that 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 and 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 for crude oil gathering and marketing and to capitalize on regional opportunities which arise from time to time for both crude oil and petroleum products.

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.

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Gathering, marketing, and logistics revenue	$	230,564	$	152,804	$	678,985	$	467,514
Crude oil pipeline tariffs and revenues	8,984		8,003		24,343		26,880
Distributions from unrestricted subsidiaries not included in income(1)	—		17,500		—		52,500
Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions	(214,004)		(128,804)		(631,720)		(415,171)
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses	(17,104)		(15,459)		(49,446)		(46,156)
Other	1,002		(4,899)		5,334		(13,055)
Segment Margin	$	9,442	$	29,145	$	27,496	$	72,512
Volumetric Data (average barrels per day unless otherwise noted):
Onshore crude oil pipelines:
Texas(2)	113,962		64,027		92,508		60,561
Jay	5,481		7,694		6,348		8,133
Mississippi	5,800		5,088		5,926		5,171
Louisiana(3)	40,171		38,454		41,024		49,305
Onshore crude oil pipelines total	165,414		115,263		145,806		123,170
Crude oil and petroleum products sales:
Total crude oil and petroleum products sales	25,613		20,878		23,860		24,292
Rail unload volumes	15,130		3,001		14,485		15,466

(1)The three and nine months ended September 30, 2021 includes total cash payments received of $17.5 million and $52.5 million, respectively, not included in income 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 three and nine months ended September 30, 2021 were impacted as a result of the CHOPS pipeline being out of service from August 26, 2020 to February 4, 2021.

(3)Total daily volume for the three and nine months ended September 30, 2022 includes 23,265 and 27,131 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines. Total daily volume for the three and nine months ended September 30, 2021 includes 37,273 and 34,041 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines.

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Onshore facilities and transportation Segment Margin for the 2022 Quarter decreased $19.7 million, or 68%, from the 2021 Quarter. This decrease is primarily due to the 2021 Quarter including cash receipts of $17.5 million associated with our previously owned NEJD pipeline. The last principal payment associated with our previously owned NEJD pipeline was received in the fourth quarter of 2021. Additionally, the 2021 Quarter included the effects of and benefited from a one-time contractual billing of approximately $10 million. This decrease was partially offset by higher rail unload, terminal, and pipeline volumes associated with our assets in the Baton Rouge corridor as well as increased volumes on our Texas pipeline. Our increase in rail volumes was a result of our main customer sourcing volumes to replace international volumes that were impacted by certain geopolitical events through August 2022, which are not expected to continue in the fourth quarter of 2022. Our Texas pipeline had increased activity during the 2022 Quarter as it is a key destination point for various grades of crude oil produced in the Gulf of Mexico including those transported on our 64% owned CHOPS pipeline.

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Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Onshore facilities and transportation Segment Margin for the first nine months of 2022 decreased $45.0 million, or 62%, primarily due to the first nine months of 2021 including cash receipts of $52.5 million associated with our previously owned NEJD pipeline. This decrease was partially offset by higher contributions to Segment Margin from our pipeline, rail, and terminal assets in the Baton Rouge corridor. While the volumes were lower on our Baton Rouge corridor assets during the first nine months of 2022 compared to the first nine months of 2021, our main customer utilized prepaid transportation credits during the period in 2021, which were fully utilized by the end of 2021. Additionally, we had higher volumes on our Texas pipeline during 2022, which is a destination point for various grades of crude oil produced in the Gulf of Mexico including those transported on our 64% owned CHOPS pipeline.

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 September 30,						Nine Months Ended September 30,
	2022			2021			2022			2021
Revenues (in thousands):
Inland freight revenues	$	27,758		$	18,006		$	74,990		$	53,752
Offshore freight revenues	20,878			19,182			63,769			50,212
Other rebill revenues(1)	29,159			11,528			71,130			32,709
Total segment revenues	$	77,795		$	48,716		$	209,889		$	136,673
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)	$	62,516		$	39,693		$	164,900		$	112,073
Segment Margin (in thousands)	$	15,279		$	9,023		$	44,989		$	24,600
Fleet Utilization:(2)
Inland Barge Utilization	100.0		%	79.9		%	97.3		%	77.7		%
Offshore Barge Utilization	94.0		%	93.5		%	96.1		%	95.2		%

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

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

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Marine transportation Segment Margin for the 2022 Quarter increased $6.3 million, or 69%, from the 2021 Quarter. 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 (while it was on hire), during the 2022 Quarter. We have continued to see an increase in demand and utilization of our vessels due to increased refinery utilization and the increased need for movements from the Gulf Coast to the East Coast for certain products. While we have continued to see increases in our day rates from both the 2021 Quarter and sequentially from the second quarter of 2022, we have continued to enter into short term contracts (less than a year) in 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. These increases were partially offset by the contribution to our reported Segment Margin from the M/T American Phoenix, as it was in its planned mandatory regulatory dry-dock from July 21, 2022 to September 16, 2022, at which time it went back on hire and is under contract for the remainder of 2022 with an investment grade customer at a more favorable rate than 2021 and the first eight months of 2022. We also recently entered into a longer-term contract with another investment grade company starting in January 2023 at an even slightly higher rate than its current charter.

Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

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Marine transportation Segment Margin for the first nine months of 2022 increased $20.4 million, or 83%, from the first nine 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 2022. 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 because we believe the day rates currently being offered by the market have yet to fully recover from their cyclical lows. These increases were partially offset by the M/T American Phoenix, as it went into her planned mandatory regulatory dry-dock from July 21, 2022 through September 16, 2022 at which time it went back on hire and under contact for the remainder of 2022 with an investment grade customer at a more favorable rate than its current charter.

Other Costs, Interest and Income Taxes

    General and administrative expenses

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
General and administrative expenses not separately identified below:
Corporate	$	13,104	$	11,646	$	38,060	$	31,435
Segment	904		1,079		2,758		3,166
Long-term incentive compensation expense	2,091		743		5,126		2,705
Third party costs related to business development activities and growth projects	939		903		6,881		1,638
Total general and administrative expenses	$	17,038	$	14,371	$	52,825	$	38,944

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Total general and administrative expenses for the 2022 Quarter increased by $2.7 million from the 2021 Quarter primarily due to higher corporate general and administrative costs and long-term incentive compensation expense as a result of the assumptions used to value our outstanding awards.

Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Total general and administrative expenses for the first nine months of 2022 increased by $13.9 million from the first nine months of 2021 primarily due to higher third party costs related to business development activities and 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 first nine months of 2022 associated with the divestiture of our previously owned Independence Hub platform. Additionally, we had increased corporate general and administrative expenses and long-term incentive compensation expense during the first nine months of 2022.

Depreciation, depletion and amortization expense

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Depreciation and depletion expense	$	71,224	$	64,441	$	208,941	$	192,907
Amortization expense	2,722		2,707		8,184		8,068
Total depreciation, depletion and amortization expense	$	73,946	$	67,148	$	217,125	$	200,975

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Total depreciation, depletion and amortization expense for the 2022 Quarter increased by $6.8 million from the 2021 Quarter. 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 2021 Quarter.

Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Total depreciation, depletion and amortization expense for the first nine months of 2022 increased by $16.2 million from the first nine months of 2021. 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 September 30, 2021.

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Interest expense, net

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
	(in thousands)				(in thousands)
Interest expense, senior secured credit facility (including commitment fees)	$	3,008	$	5,494	$	6,635	$	18,737
Interest expense, Alkali senior secured notes	6,352		—		9,457		—
Interest expense, senior unsecured notes	51,476		53,079		157,535		153,273
Amortization of debt issuance costs, premium and discount	2,166		2,276		6,317		7,246
Capitalized interest	(5,292)		(909)		(11,171)		(2,318)
Interest expense, net	$	57,710	$	59,940	$	168,773	$	176,938

Three Months Ended September 30, 2022 Compared with Three Months Ended September 30, 2021

Net interest expense for the 2022 Quarter decreased by $2.2 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 from the sale of a noncontrolling interest in our CHOPS pipeline in November 2021; and (ii) the proceeds we received from the issuance of our Alkali senior secured notes in May 2022 in excess of the funds used to redeem our Alkali Holdings preferred units, 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 secured notes due 2042 that were issued during May 2022, which bears interest at 5.875%.

Nine Months Ended September 30, 2022 Compared with Nine Months Ended September 30, 2021

Net interest expense for the first nine months of 2022 decreased by $8.2 million primarily due to lower interest on our senior secured credit facility. 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 proceeds we received from the issuance of our Alkali senior secured notes in May 2022 in excess of the funds used to redeem our Alkali Holdings preferred units, 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 senior unsecured notes as a result of our additional issuance of $250 million in aggregate principal of our 2027 Notes in April 2021, which bears interest at 8% and the issuance of our Alkali senior secured notes due 2042 on May 17, 2022, which bears interest 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 credit agreement, which initially provided for a $950 million senior secured credit facility, comprised of our Revolving Loan with a borrowing capacity of $650 million and our Term Loan with a borrowing capacity of $300 million, with 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. 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.

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 as our 2027 Notes and 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 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 quarterly principal and interest 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 under 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 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 credit agreement (including its extended maturity and leverage flexibility), 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 and has provided us a significant amount of available borrowing capacity under our Revolving Loan, subject to compliance with the covenants in our credit agreement, to, amongst other things, utilize for funding the remaining growth capital expenditures associated with the Granger expansion and our offshore growth projects discussed in further detail below. On April 29, 2022, 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. The available borrowing capacity under our Revolving Loan at September 30, 2022 is $525.3 million.

We anticipate that our future internally-generated funds and the funds available under our 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 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 and 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 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, and to implement our growth strategy successfully. No assurance can be made that we will be able to raise necessary funds on satisfactory terms.

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At September 30, 2022, our long-term debt totaled approximately $3.4 billion, consisting of $120.2 million outstanding under our senior secured credit facility (including $11.3 million borrowed under the inventory sublimit tranche), $2.9 billion of senior unsecured notes, net and $402.3 million of Alkali senior secured notes, net, which are secured by the ORRI Interests. Our senior unsecured notes, net balance is comprised of $339.7 million carrying amount due June 2024, $531.3 million carrying amount due October 2025, $336.6 million carrying amount due May 2026, $975.9 million carrying value due January 2027 and $671.4 million carrying amount due February 2028. We remain focused on continuing to reduce our leverage.

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”) 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 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 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, 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 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 alkali products. Additionally, we may be required to deposit margin funds associated with exchange-traded commodity derivative contracts 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 2022 and 2021.

Net cash flows provided by our operating activities for the nine months ended September 30, 2022 were $252.6 million compared to $242.4 million for the nine months ended September 30, 2021. The increase in cash flows from operating activities is primarily attributable to our reported increase in Segment Margin partially offset by changes in working capital between the two periods primarily due to higher interest payments and 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 interest payments.

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Capital Expenditures and Distributions Paid to Our Unitholders

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

Capital Expenditures for Fixed and Intangible Assets and Equity Investees

The following table summarizes our expenditures for fixed and intangible assets and equity investees in the periods indicated:

	Nine Months Ended September 30,
	2022		2021
	(in thousands)
Capital expenditures for fixed and intangible assets:
Maintenance capital expenditures:
Offshore pipeline transportation assets	$	5,127	$	8,166
Sodium minerals and sulfur services assets	49,965		30,458
Marine transportation assets	28,704		29,757
Onshore facilities and transportation assets	1,715		4,382
Information technology systems and corporate assets	5,012		293
Total maintenance capital expenditures	90,523		73,056
Growth capital expenditures:
Offshore pipeline transportation assets	157,785		26,473
Sodium minerals and sulfur services assets	64,733		127,723
Onshore facilities and transportation assets	—		133
Information technology systems and corporate assets	6,960		6,338
Total growth capital expenditures	229,478		160,667
Total capital expenditures for fixed and intangible assets	320,001		233,723
Capital expenditures related to equity investees	5,441		129
Total capital expenditures	$	325,442	$	233,852

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 along with the issuance of the Alkali Holdings preferred units, which were anticipated to fund up to the total estimated cost of the GOP. The anticipated completion date of the project is the third quarter of 2023. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year. During the fourth quarter of 2021, we made the decision to fund the remaining capital expenditures associated with the GOP internally in lieu of issuing additional Alkali Holdings preferred units.

During 2022, we 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 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.

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We plan to fund our estimated growth capital expenditures utilizing the available borrowing capacity under our Revolving Loan and our recurring cash flows generated from operations, which we anticipate to increase throughout 2022 and into 2023 as a result of 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 2022 primarily related to expenditures in 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 Alkali Business, which is included in our sodium minerals and sulfur services segment, due to the costs to maintain our related equipment and facilities. Additionally, our offshore transportation assets incur maintenance capital expenditures to replace, maintain and upgrade equipment at certain of our offshore platforms and pipelines that we operate. See further discussion under “Available Cash before Reserves” for how such maintenance capital utilization is reflected in our calculation of Available Cash before Reserves.

Distributions to Unitholders

On August 12, 2022, we paid a distribution of $0.15 per unit related to the second 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 August 12, 2022 to unitholders holders of record at the close of business July 29, 2022.

On October 10, 2022, we announced the distribution of $0.15 per common unit totaling $18.4 million with respect to the 2022 Quarter and a 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 November 14, 2022 to unitholders of record at the close of business on October 31, 2022. As a result of the one-time Rate Reset Election made by the holders of the Class A Convertible Preferred Units, the annual distribution rate for the Class A Convertible Preferred Units increased from 8.75% to 11.24%, applicable for future quarterly distributions declared and payable, beginning with the quarter ended December 31, 2022. Information on our recent distribution history and discussion regarding the annual distribution rate reset of our Class A Convertible Preferred Units 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 current and future 100% owned domestic subsidiaries (the “Guarantor Subsidiaries”), except GA ORRI and 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. 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. 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.

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.

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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-designated Genesis 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, 2022, 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 are now 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
	September 30, 2022
ASSETS:
Current assets	$	675,087
Fixed assets and mineral leaseholds, net	3,631,055
Non-current assets	874,911
LIABILITIES AND CAPITAL:(1)
Current liabilities	613,573
Non-current liabilities	3,540,840
Class A Convertible Preferred Units	891,909

Statement of Operations	Genesis Energy, L.P. and Guarantor Subsidiaries
	Nine Months Ended September 30, 2022
Revenues	$	1,970,301
Operating costs	1,835,180
Operating income	135,121
Income before income taxes	5,409
Net income(1)	3,898
Less: Accumulated distributions to Class A Convertible Preferred Units	(56,052)
Net loss attributable to common unitholders	(52,154)

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

Excluded from non-current assets in the table above is $13.9 million of net intercompany receivables due to Genesis Energy, L.P. and the Guarantor Subsidiaries from the Non-Guarantor Subsidiaries as of September 30, 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 Financial Measures” as later discussed and defined.

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

	Three Months Ended September 30,
	2022		2021
	(in thousands)
Net income (loss) attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)
Income tax expense	660		423
Depreciation, depletion, amortization and accretion	76,301		69,665
Plus (minus) Select Items, net	45,583		24,309
Maintenance capital utilized(1)	(14,400)		(13,500)
Cash tax expense	(250)		(195)
Distributions to preferred unitholders	(18,684)		(18,684)
Redeemable noncontrolling interest redemption value adjustments(2)	—		7,082
Available Cash before Reserves	$	92,595	$	48,201

(1)For a description of the term “maintenance capital utilized”, please see the definition of the term “Available Cash before Reserves” discussed below. Maintenance capital expenditures in the 2022 Quarter and 2021 Quarter were $44.3 million and $23.1 million, respectively.

(2)The 2021 Quarter includes PIK distributions and accretion on the redemption feature. The associated Alkali Holdings preferred units were fully redeemed during the second quarter of 2022.

We define Available Cash before Reserves (“Available Cash before Reserves”) as 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, interest expense and cash 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.

		Three Months Ended September 30,
		2022		2021
		(in thousands)
I.	Applicable to all Non-GAAP Measures
	Differences in timing of cash receipts for certain contractual arrangements(1)	$	13,775	$	657
	Distribution from unrestricted subsidiaries not included in income(2)	—		17,500
	Certain non-cash items:
	Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value(3)	26,295		(1,708)
	Loss on debt extinguishment	293		—
	Adjustment regarding equity investees(4)	5,247		7,142
	Other	(1,659)		(818)
	Sub-total Select Items, net	43,951		22,773
II.	Applicable only to Available Cash before Reserves
	Certain transaction costs	939		903
	Other	693		633
	Total Select Items, net(5)	$	45,583	$	24,309

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(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 2021 Quarter includes $17.5 million in cash receipts associated with principal repayments on our previously owned NEJD pipeline not included in income. We received the last 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 senior secured credit facility.

(3)The 2022 Quarter includes an unrealized loss of $25.0 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The 2021 Quarter includes an unrealized gain of $1.7 million from the valuation of the embedded 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 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 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; liquidity and similar measures; income; cash flow expectations for us; and certain information regarding some of our peers. Additionally, our board of 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 measures such as net income, operating income, cash flow from operating activities or any other GAAP measure of liquidity or financial performance.

Segment Margin

We define Segment Margin as revenues less product costs, operating expenses and segment general and administrative expenses (all of 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 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:

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(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 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.

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. 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.

Beginning with 2014, we 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. 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 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.

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,

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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 maintenance capital utilized calculations will reflect the utilization of solely those maintenance capital expenditures incurred since December 31, 2013.

Critical Accounting Estimates

There have been no new or material changes to the critical accounting estimates discussed in our Annual Report that are of significance, or potential significance, to the 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, 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 economic activity, capital expenditures by energy producers, weather, alternative energy sources, international events (including the war in Ukraine), global pandemics, 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 cost saving measures;

•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;

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•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, including the result of any economic recession or depression that has occurred or may occur in the future;

•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;

•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.

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 rules and forms. As described in our Quarterly Report on Form 10-Q for the period ended June 30, 2022, management identified a material weakness in our internal control over financial reporting during the quarter ended June 30, 2022. The Company implemented measures in an effort to remediate the material weakness and enhance the Company’s accounting and review processes during the three months ended September 30, 2022, which included the following actions: (i) implementing additional review procedures; and (ii) participating in various continuing education courses associated with the review of revenue contracts.

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 and believe it is appropriate to continue monitoring the effectiveness of the Company’s implemented remediation efforts before making a final determination that our disclosure controls and procedures are effective. As such, as a result of the material weakness discovered during the second quarter 2022 and the Company’s ongoing monitoring of the implemented remediation, management has assessed that our disclosure controls and procedures are not effective in ensuring that material information required to be disclosed in this Quarterly Report on Form 10-Q is accumulated and communicated to them and our management to allow timely decisions regarding required disclosures. The material weakness did not, however, result in a misstatement to the reported consolidated financial statements, and notwithstanding the material 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. Management expects to conclude that the material weakness described above is fully remediated by the end of this fiscal year.

Changes in Internal Control Over Financial Reporting

Except as noted above, there have been no changes in internal control over financial reporting during the quarter ended September 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, 2021 (the “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, 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 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 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 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 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 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 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 Annual Report on Form 10-K for the year ended December 31, 2007, File No. 001-12295).
	22.1	List of Issuers and Guarantor Subsidiaries (incorporated by reference to Exhibit 22.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2022, File No. 001-12295)
*	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

55

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:	October 27, 2022	By:	/s/ ROBERT V. DEERE
			Robert V. Deere
			Chief Financial Officer
			(Duly Authorized Officer)

56

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Grant E. Sims, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Genesis Energy, L.P.;

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

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

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

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

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

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

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

5.The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors:

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

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

Date:	October 27, 2022	/s/ Grant E. Sims
		Grant E. Sims
		Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Robert V. Deere, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Genesis Energy, L.P.;

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

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

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

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

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

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

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

5.The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors:

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

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

Date:	October 27, 2022	/s/ Robert V. Deere
		Robert V. Deere
		Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

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

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of Genesis Energy, L.P. (the “Partnership”) for the period ended September 30, 2022 (the “Report”) filed with the Securities and Exchange Commission on the date hereof, the undersigned, Grant E. Sims, Chief Executive Officer and Robert V. Deere, Chief Financial Officer of Genesis Energy, LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Partnership’s Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 as amended; and

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

October 27, 2022	/s/ Grant E. Sims
	Grant E. Sims
	Chief Executive Officer,
	Genesis Energy, LLC
October 27, 2022	/s/ Robert V. Deere
	Robert V. Deere
	Chief Financial Officer,
	Genesis Energy, LLC

EX-95

Exhibit 95

MINE SAFETY DISCLOSURES

Section 1503 of the Dodd-Frank Act contains reporting requirements regarding coal or other mine safety. In conjunction with our acquisition of Tronox Limited’s (“Tronox”) (NYSE:TROX) trona and trona-based exploring, mining, processing, producing, marketing and selling business (the “Alkali Business”) on September 1, 2017,we acquired and now operate a mine at the Green River, Wyoming facility.Our mine is subject to regulation by the Mine Safety and Health Administration (“MSHA”) under the Federal Mine Safety and Health Act of 1977 (the “Mine Act”), and is therefore subject to these reporting requirements. Presented in the table below is information regarding certain mining safety and health citations which MSHA has issued with respect to our operation as required by the Dodd-Frank Act. In evaluating this information, consideration should be given to the fact that citations and orders can be contested and appealed, and in that process, may be reduced in severity, penalty amount or sometimes dismissed (vacated) altogether.

The letters used as column headings in the table below correspond to the explanations provided underneath the table as to the information set forth in each column with respect to the numbers of violations, orders, citations or dollar amounts, as the case may be, during the third quarter of 2022 unless otherwise indicated.

(A)

(B)

(C)

(D)

(E)

(F)

(G)

(H)

(I)

(J)

(K)

(L)

Mine or Operating Name/ MSHA Identification Number

Section 104 S&S Citations (#)

Section 104(b) Orders (#)

Section 104(d) Citations and Orders (#)

Section 110(b)(2) Violations (#)

Section 107(a) Orders (#)

Total Dollar Value of MSHA Assessment Proposed ($)

Total Number of Mining Related Fatalities (#)

Received Notice of Pattern of Violations Under Section 104(e) (yes/no)

Received Notice of Potential to Have Pattern Under Section 104(e) (yes/no)

Legal Actions Pending as of Last Day of Period (#)

Legal Actions Initiated During Period (#)

Legal Actions Resolved During Period (#)

Genesis-Alkali at Westvaco MSHA I.D. No.: 48-00152

12

0

1

0

0

$39,380

0

No

No

9

4

2

(A)The total number of violations of mandatory health or safety standards that could significantly and substantially contribute to the cause and effect of a coal or other mine safety and health hazard under section 104 of the Mine Act for which the operator received a citation from MSHA.

(B)The total number of orders issued under section 104(b) of the Mine Act.

(C)The total number of citations and orders for unwarrantable failure of the operator to comply with mandatory health or safety standards under section 104(d) of the Mine Act.

(D)The total number of flagrant violations under section 110(b)(2) of the Mine Act.

(E)The total number of imminent danger orders issued under section 107(a) of the Mine Act.

(F)The total dollar value of proposed assessments from the MSHA under the Mine Act. Only includes assessments proposed for citations issued in third quarter 2022.

(G)The total number of mining related fatalities.

(H)During the quarter ending September 30, 2022, the mine did not receive Notice of Pattern of Violations under Section 104(e)

(I)During the quarter ending September 30, 2022, the mine did not receive Notice of a Potential to have a Pattern of Violations Under Section 104(e)

(J)Includes all legal actions before the Federal Mine Safety and Review Commission, together with the Administrative Law Judges thereof, for our operations.

(K)The total number of legal actions were initiated by us to contest citations, orders or proposed assessments issued by the federal Mine Safety and Health Administration during the third quarter 2022.

(L)Previously initiated legal action to contest citations, orders or proposed assessments issued by the federal Mine Safety and Health Administration, which if successful, could result in the reduction or dismissal of those citations, orders or assessments, resolved during the period.

XML

Cover - shares	9 Months Ended
	Sep. 30, 2022	Oct. 26, 2022
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	1-12295
Entity Registrant Name	GENESIS ENERGY LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	76-0513049
Entity Address, Address Line One	811 Louisiana, Suite 1200,
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	(713)
Local Phone Number	860-2500
Title of 12(b) Security	Common units
Trading Symbol	GEL
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001022321
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Amendment Flag	false
Class A Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		122,539,221
Class B Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		39,997

XML

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
CURRENT ASSETS:
Cash and cash equivalents	$ 5,848	$ 19,987
Restricted cash	18,637	5,005
Accounts receivable - trade, net	575,927	400,334
Inventories	92,907	77,958
Other Assets, Current	33,111	39,200
Total current assets	726,430	542,484
FIXED ASSETS, at cost	5,731,630	5,464,040
Less: Accumulated depreciation	(1,711,306)	(1,551,855)
Net fixed assets	4,020,324	3,912,185
MINERAL LEASEHOLDS, net of accumulated depletion	546,175	549,005
EQUITY INVESTEES	285,417	294,050
INTANGIBLE ASSETS, net of amortization	127,201	127,063
GOODWILL	301,959	301,959
RIGHT OF USE ASSETS, net	128,288	140,796
Other assets - net of amortization	33,745	38,259
TOTAL ASSETS	6,169,539	5,905,801
CURRENT LIABILITIES:
Accounts payable - trade	378,367	264,316
Accrued liabilities	266,950	232,623
Total current liabilities	645,317	496,939
Long-term Line of Credit, Noncurrent	120,200	49,000
SENIOR SECURED CREDIT FACILITY	402,254	0
SENIOR UNSECURED NOTES, net of debt issuance costs and premium	2,854,874	2,930,505
DEFERRED TAX LIABILITIES	15,307	14,297
OTHER LONG-TERM LIABILITIES	373,397	434,925
Total liabilities	4,411,349	3,925,666
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at September 30, 2022 and December 31, 2021	891,909	790,115
Redeemable noncontrolling interests, no units issued and outstanding at September 30, 2022 and 246,394 preferred units issued and outstanding December 31, 2021	0	259,568
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at September 30, 2022 and December 31, 2021	562,373	641,313
Accumulated other comprehensive loss	(5,242)	(5,607)
Noncontrolling interests	309,150	294,746
Total partners’ capital	866,281	930,452
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ 6,169,539	$ 5,905,801

XML

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2022	Dec. 31, 2021
Common units issued (in units)	122,579,218	122,579,218
Common units outstanding (in units)	122,579,218	122,579,218
Class A Convertible Preferred Stock Units
Number preferred units issued (in units)	25,336,778	25,336,778
Number of preferred units outstanding (in units)	25,336,778	25,336,778
Redeemable Noncontrolling Interest Preferred Units
Number preferred units issued (in units)		246,394
Number of preferred units outstanding (in units)		246,394

XML

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
REVENUES:
Total revenues	$ 721,248	$ 518,821	$ 2,074,920	$ 1,543,895
COSTS AND EXPENSES:
General and administrative	17,038	14,371	52,825	38,944
Depreciation, depletion and amortization	73,946	67,148	217,125	200,975
Gain (Loss) on Disposition of Assets	0	0	(40,000)	0
Total costs and expenses	646,153	484,327	1,851,569	1,455,843
OPERATING INCOME	75,095	34,494	223,351	88,052
Equity in earnings of equity investees	13,236	10,301	40,252	45,183
Interest expense	(57,710)	(59,940)	(168,773)	(176,938)
Other income (expense)	(21,388)	1,741	(10,758)	(34,169)
Income (loss) from operations before income taxes	9,233	(13,404)	84,072	(77,872)
Income tax expense	(660)	(423)	(1,535)	(1,170)
NET INCOME (LOSS)	8,573	(13,827)	82,537	(79,042)
Net loss (income) attributable to noncontrolling interests	(5,188)	10	(18,612)	(124)
Net income attributable to redeemable noncontrolling interests	0	(7,082)	(30,443)	(17,639)
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.	3,385	(20,899)	33,482	(96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)	(18,684)	(56,052)	(56,052)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(15,299)	(39,583)	(22,570)	(152,857)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (15,299)	$ (39,583)	$ (22,570)	$ (152,857)
NET LOSS PER COMMON UNIT (Note 11):
Basic (in dollars per unit)	$ (0.12)	$ (0.32)	$ (0.18)	$ (1.25)
Diluted (in dollars per unit)	$ (0.12)	$ (0.32)	$ (0.18)	$ (1.25)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic (in units)	122,579	122,579	122,579	122,579
Diluted (in units)	122,579	122,579	122,579	122,579
Offshore pipeline transportation
REVENUES:
Total revenues	$ 89,805	$ 69,479	$ 239,958	$ 207,084
COSTS AND EXPENSES:
Cost of products and services sold	25,410	21,080	74,785	63,060
Sodium minerals and sulfur services
REVENUES:
Total revenues	312,681	237,651	916,963	702,025
COSTS AND EXPENSES:
Cost of products and services sold	235,308	196,656	699,847	578,058
Marine transportation
REVENUES:
Total revenues	77,795	48,716	209,889	136,673
COSTS AND EXPENSES:
Cost of products and services sold	63,074	39,782	165,726	111,986
Onshore facilities and transportation
REVENUES:
Total revenues	240,967	162,975	708,110	498,113
Onshore facilities and transportation | Onshore facilities and transportation product costs
COSTS AND EXPENSES:
Cost of products and services sold	213,680	129,498	630,985	414,933
Onshore facilities and transportation | Onshore facilities and transportation operating costs
COSTS AND EXPENSES:
Cost of products and services sold	$ 17,697	$ 15,792	$ 50,276	$ 47,887

XML

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Net loss	$ 8,573	$ (13,827)	$ 82,537	$ (79,042)
Other comprehensive income:
Amortization of prior year service cost	122	122	365	365
Total Comprehensive income (loss)	8,695	(13,705)	82,902	(78,677)
Comprehensive loss (income) attributable to noncontrolling interests	(5,188)	10	(18,612)	(124)
Comprehensive income attributable to redeemable noncontrolling interests	0	(7,082)	(30,443)	(17,639)
Comprehensive income (loss) attributable to Genesis Energy, L.P.	$ 3,507	$ (20,777)	$ 33,847	$ (96,440)

XML

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL - USD ($) shares in Thousands, $ in Thousands	Total	Limited Partner [Member]	Limited Partner [Member] Common Units	Noncontrolling Interest [Member]	AOCI Attributable to Parent [Member]
Partners' capital, beginning balance (in shares) at Dec. 31, 2020			122,579
Partners' capital, beginning balance at Dec. 31, 2020	$ 818,848	$ 829,326		$ (1,113)	$ (9,365)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	(96,681)	(96,805)		124
Cash distributions to partners	(55,161)	(55,161)
Cash contributions from noncontrolling interests	557			557
Other comprehensive income	365				365
Distributions to Class A Convertible Preferred unitholders	(56,052)	(56,052)
Partners' capital, ending balance (in shares) at Sep. 30, 2021			122,579
Partners' capital, ending balance at Sep. 30, 2021	611,876	621,308		(432)	(9,000)
Partners' capital, beginning balance (in shares) at Jun. 30, 2021			122,579
Partners' capital, beginning balance at Jun. 30, 2021	669,562	679,278		(594)	(9,122)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	(20,909)	(20,899)		(10)
Cash distributions to partners	(18,387)	(18,387)
Cash contributions from noncontrolling interests	172			172
Other comprehensive income	122				122
Distributions to Class A Convertible Preferred unitholders	(18,684)	(18,684)
Partners' capital, ending balance (in shares) at Sep. 30, 2021			122,579
Partners' capital, ending balance at Sep. 30, 2021	611,876	621,308		(432)	(9,000)
Partners' capital, beginning balance at Dec. 31, 2021	930,452	641,313		294,746	(5,607)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	52,094	33,482		18,612
Cash distributions to partners	(55,161)	(55,161)
Adjustment to valuation of noncontrolling interest in subsidiary	0	(1,209)		1,209
Cash distributions to noncontrolling interests	(24,656)			(24,656)
Cash contributions from noncontrolling interests	19,239			19,239
Other comprehensive income	365				365
Distributions to Class A Convertible Preferred unitholders	(56,052)	(56,052)
Partners' capital, ending balance (in shares) at Sep. 30, 2022			122,579
Partners' capital, ending balance at Sep. 30, 2022	866,281	562,373		309,150	(5,242)
Partners' capital, beginning balance (in shares) at Jun. 30, 2022			122,579
Partners' capital, beginning balance at Jun. 30, 2022	890,541	596,059		299,846	(5,364)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	8,573	3,385		5,188
Cash distributions to partners	(18,387)	(18,387)
Cash distributions to noncontrolling interests	(6,324)			(6,324)
Cash contributions from noncontrolling interests	10,440			10,440
Other comprehensive income	122				122
Distributions to Class A Convertible Preferred unitholders	(18,684)	(18,684)
Partners' capital, ending balance (in shares) at Sep. 30, 2022			122,579
Partners' capital, ending balance at Sep. 30, 2022	$ 866,281	$ 562,373		$ 309,150	$ (5,242)

XML

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ 82,537	$ (79,042)
Adjustments to reconcile net income (loss) to net cash provided by operating activities -
Depreciation, depletion and amortization	217,125	200,975
Gain (Loss) on Disposition of Assets	(40,000)	0
Amortization and write-off of debt issuance costs, premium and discount	7,110	9,242
Payments received under previously owned direct financing leases	0	52,500
Equity in earnings of investments in equity investees	(40,252)	(45,183)
Cash distributions of earnings of equity investees	41,496	44,747
Non-cash effect of long-term incentive compensation plans	10,835	5,111
Deferred and other tax liabilities	1,010	630
Unrealized losses on derivative transactions	15,726	30,729
Cancellation of debt income	(8,619)	0
Other, net	14,203	16,191
Net changes in components of operating assets and liabilities (Note 14)	(48,576)	6,457
Net cash provided by operating activities	252,595	242,357
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(303,789)	(217,972)
Cash distributions received from equity investees - return of investment	14,737	24,126
Investments in equity investees	(5,441)	(129)
Proceeds from asset sales	40,281	223
Net cash used in investing activities	(254,212)	(193,752)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	697,000	553,100
Repayments on senior secured credit facility	(625,800)	(763,800)
Proceeds from Issuance of Senior Long-term Debt	408,000	0
Redemption of preferred units (Note 10)	288,629	0
Proceeds from issuance of senior unsecured notes (Note 9)	0	259,375
Net proceeds from issuance of preferred units	0	93,100
Repayment of senior unsecured notes (Note 9)	(72,241)	(80,859)
Debt issuance costs	(6,019)	(12,208)
Contributions from noncontrolling interests	19,239	557
Distributions to noncontrolling interests	(24,656)	0
Distributions to common unitholders	(55,161)	(55,161)
Distributions to Class A Convertible Preferred unitholders	(56,052)	(56,052)
Other, net	5,429	1,821
Net cash provided by (used in) financing activities	1,110	(60,127)
Net decrease in cash, cash equivalents and restricted cash	(507)	(11,522)
Cash, cash equivalents and restricted cash at beginning of period	24,992	27,018
Cash, cash equivalents and restricted cash at end of period	$ 24,485	$ 15,496

XML

Organization and Basis of Presentation and Consolidation

9 Months Ended

Sep. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation and Consolidation

Organization and Basis of Presentation and Consolidation

Organization

We are a growth-oriented master limited partnership 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 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”), 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 four divisions that constitute our reportable segments:

•Offshore pipeline transportation, 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, marketing and selling activities, as well as soda ash production and processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and selling the related by-product, sodium hydrosulfide (or “NaHS,” commonly pronounced “nash”);

•Onshore facilities and transportation, which include terminaling, blending, storing, marketing and transporting 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

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”). 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”) 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, 2021 (our “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.

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Recent Accounting Developments	9 Months Ended
	Sep. 30, 2022
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting DevelopmentsRecent and Proposed Accounting PronouncementsIn March 2020, the 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 anticipated discontinuation of the 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 replacement of a 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 among other things, replaced our existing LIBOR rate based borrowings with the Term SOFR rate, which is based on the Secured Overnight Financing Rate (“SOFR”) borrowings. The impact to our senior secured credit facility and related interest expense upon

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Revenue Recognition

9 Months Ended

Sep. 30, 2022

Revenue Recognition [Abstract]

Revenue Recognition

Revenue Recognition

Revenue from Contracts with Customers

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

	Three Months Ended September 30, 2022
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	89,805	$	—	$	77,795	$	20,177	$	187,777
Product Sales	—		290,620		—		220,790		511,410
Refinery Services	—		22,061		—		—		22,061
	$	89,805	$	312,681	$	77,795	$	240,967	$	721,248

	Three Months Ended September 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities & Transportation		Consolidated
Fee-based revenues	$	69,479	$	—	$	48,716	$	26,603	$	144,798
Product Sales	—		210,997		—		136,372		347,369
Refinery Services	—		26,654		—		—		26,654
	$	69,479	$	237,651	$	48,716	$	162,975	$	518,821

The following tables reflect the disaggregation of our revenues by major category for the nine months ended September 30, 2022 and 2021, respectively:

	Nine Months Ended September 30, 2022
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	239,958	$	—	$	209,889	$	54,280	$	504,127
Product Sales	—		837,335		—		653,830		1,491,165
Refinery Services	—		79,628		—		—		79,628
	$	239,958	$	916,963	$	209,889	$	708,110	$	2,074,920

	Nine Months Ended September 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	207,084	$	—	$	136,673	$	69,173	$	412,930
Product Sales	—		628,209		—		428,940		1,057,149
Refinery Services	—		73,816		—		—		73,816
	$	207,084	$	702,025	$	136,673	$	498,113	$	1,543,895

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. During the

three and nine months ended September 30, 2021, we recorded immaterial amounts of revenue associated with prior periods of

approximately $10.7 million and $8.2 million, respectively, of which the majority was noncash.

Contract Assets and Liabilities

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

	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 September 30, 2022	—		16,662		35,602

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 September 30, 2022. We are 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.

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 2022	$	19,314	$	1,800
2023	67,941		7,200
2024	60,970		1,800
2025	64,292		—
2026	45,834		—
Thereafter	57,748		—
Total	$	316,099	$	10,800

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Lease Accounting

9 Months Ended

Sep. 30, 2022

Leases [Abstract]

Lease Accounting

Lease Accounting

Lessee Arrangements

We lease a variety of transportation equipment (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 and we recognize lease expense for these leases on a straight-line basis over the lease term.

Our “Right of Use Assets, 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” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets.

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 nine months ended September 30, 2022 and 2021, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, which is included in our marine transportation segment. Our lease revenues for this arrangement (inclusive of fixed and variable consideration) were $1.8 million and $4.1 million for the three months ended September 30, 2022 and 2021, respectively, and $10.5 million and $11.4 million for the nine months ended September 30, 2022 and 2021, respectively.

Lease Accounting

Lease Accounting

Lessee Arrangements

We lease a variety of transportation equipment (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 and we recognize lease expense for these leases on a straight-line basis over the lease term.

Our “Right of Use Assets, 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” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets.

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 nine months ended September 30, 2022 and 2021, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, which is included in our marine transportation segment. Our lease revenues for this arrangement (inclusive of fixed and variable consideration) were $1.8 million and $4.1 million for the three months ended September 30, 2022 and 2021, respectively, and $10.5 million and $11.4 million for the nine months ended September 30, 2022 and 2021, respectively.

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Inventories

9 Months Ended

Sep. 30, 2022

Inventory Disclosure [Abstract]

Inventories

Inventories

The major components of inventories were as follows:

	September 30, 2022		December 31, 2021
Petroleum products	$	3,054	$	998
Crude oil	15,451		11,834
Caustic soda	11,636		5,690
NaHS	18,236		17,040
Raw materials - Alkali operations	6,672		7,599
Work-in-process - Alkali operations	8,299		7,496
Finished goods, net - Alkali operations	14,281		13,681
Materials and supplies, net - Alkali operations	15,278		13,620
Total	$	92,907	$	77,958

Inventories are valued at the lower of cost or net realizable value. As of September 30, 2022 and December 31, 2021, the net realizable value of inventories were below cost by $2.4 million and $2.0 million, respectively, which triggered a reduction of the value of inventory in our Consolidated Financial Statements by 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.

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations

9 Months Ended

Sep. 30, 2022

Fixed Assets And Asset Retirement Obligations [Abstract]

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations

Fixed Assets, Mineral Leaseholds and Asset Retirement Obligations

Fixed Assets

Fixed assets consisted of the following:

	September 30, 2022		December 31, 2021
Crude oil and natural gas pipelines and related assets	$	2,840,829	$	2,839,443
Alkali facilities, machinery and equipment	688,569		670,880
Onshore facilities, machinery and equipment	269,249		269,245
Transportation equipment	22,032		21,106
Marine vessels	1,013,713		1,018,284
Land, buildings and improvements	229,202		227,540
Office equipment, furniture and fixtures	27,066		23,965
Construction in progress	599,802		350,137
Other	41,168		43,440
Fixed assets, at cost	5,731,630		5,464,040
Less: Accumulated depreciation	(1,711,306)		(1,551,855)
Net fixed assets	$	4,020,324	$	3,912,185

Mineral Leaseholds

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

	September 30, 2022		December 31, 2021
Mineral leaseholds	$	566,019	$	566,019
Less: Accumulated depletion	(19,844)		(17,014)
Mineral leaseholds, net of accumulated depletion	$	546,175	$	549,005

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Depreciation expense	$	70,328	$	63,482	$	206,111	$	190,332
Depletion expense	896		959		2,830		2,575

Asset Retirement Obligations

We record asset retirement obligations (“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, 2021:

ARO liability balance, December 31, 2021	$	220,906
Accretion expense	10,175
Changes in estimate	3,189
Settlements	(12,267)
ARO liability balance, September 30, 2022	$	222,003

At September 30, 2022 and December 31, 2021, $28.8 million and $36.3 million are included as current in “Accrued liabilities” on our Unaudited Condensed Consolidated Balance Sheets, respectively. The remainder of the ARO liability as of September 30, 2022 and December 31, 2021 is included in “Other long-term liabilities” on our Unaudited Condensed Consolidated Balance Sheets.

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

Remainder of	2022	$	2,909
	2023	$	10,640
	2024	$	9,827
	2025	$	10,532
	2026	$	8,281

Certain of our unconsolidated affiliates have AROs recorded at September 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.

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Equity Investees

9 Months Ended

Sep. 30, 2022

Equity Method Investments and Joint Ventures [Abstract]

Equity Investees

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 September 30, 2022 and December 31, 2021, the unamortized excess cost amounts totaled $309.2 million and $319.9 million, respectively. We amortize the differences in carrying value as 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 September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Genesis’ share of operating earnings	$	16,802	$	14,174	$	50,950	$	56,801
Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)		(3,873)		(10,698)		(11,618)
Net equity in earnings	$	13,236	$	10,301	$	40,252	$	45,183
Distributions received(1)	$	18,483	$	17,443	$	56,233	$	68,873

(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):

	September 30, 2022		December 31, 2021
BALANCE SHEETS DATA:
Assets
Current assets	$	27,448	$	17,827
Fixed assets, net	150,416		160,379
Other assets	11,958		6,186
Total assets	$	189,822	$	184,392
Liabilities and equity
Current liabilities	$	12,667	$	7,668
Other liabilities	234,401		231,970
Equity (Deficit)	(57,246)		(55,246)
Total liabilities and equity	$	189,822	$	184,392

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
STATEMENTS OF OPERATIONS DATA:
Revenues	$	38,322	$	27,262	$	104,891	$	103,432
Operating income	$	27,731	$	18,762	$	75,540	$	75,559
Net income	$	25,502	$	17,718	$	70,850	$	72,473

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 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.

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Intangible Assets

9 Months Ended

Sep. 30, 2022

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Intangible Assets

Intangible Assets

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

	September 30, 2022						December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Marine contract intangibles	$	800	$	634	$	166	$	800	$	607	$	193
Offshore pipeline contract intangibles	158,101		59,635		98,466		158,101		53,394		104,707
Other	45,811		17,242		28,569		37,933		15,770		22,163
Total	$	204,712	$	77,511	$	127,201	$	196,834	$	69,771	$	127,063

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Amortization of intangible assets	$	2,575	$	2,575	$	7,740	$	7,755

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

Remainder of	2022	$	3,132
	2023	$	12,302
	2024	$	11,937
	2025	$	11,712
	2026	$	11,412

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Debt

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Debt

Debt

Our obligations under debt arrangements consisted of the following:

	September 30, 2022						December 31, 2021
	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)	$	120,200	$	—	$	120,200	$	49,000	$	—	$	49,000
5.625% senior unsecured notes due 2024	341,135		1,464		339,671		341,135		2,106		339,029
6.500% senior unsecured notes due 2025	534,834		3,562		531,272		534,834		4,452		530,382
6.250% senior unsecured notes due 2026	339,310		2,664		336,646		359,799		3,410		356,389
8.000% senior unsecured notes due 2027	981,245		5,325		975,920		1,000,000		6,592		993,408
7.750% senior unsecured notes due 2028	679,360		7,995		671,365		720,975		9,678		711,297
5.875% Alkali senior secured notes due 2042	425,000		22,746		402,254		—		—		—
Total long-term debt	$	3,421,084	$	43,756	$	3,377,328	$	3,005,743	$	26,238	$	2,979,505

(1)    Unamortized debt issuance costs associated with our Revolving Loan, as defined below (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were $3.1 million and $4.7 million as of September 30, 2022 and December 31, 2021, respectively.

Senior Secured Credit Facility

On April 8, 2021, we entered into the Fifth Amended and Restated Credit Agreement (the “credit agreement”) to replace our Fourth Amended and Restated Credit 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”) and a term loan facility of $300 million (the “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 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.

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 September 30, 2022, the key terms for rates under our Revolving Loan (which are dependent on our leverage ratio as defined in the credit agreement amendment) are as follows:

•The interest rate on borrowings may be based on an alternate base rate or Term SOFR, at our option. Interest on alternate base rate loans is equal to the sum of (a) the 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% and (iii) the Adjusted Term SOFR (as defined in our credit agreement amendment) for a one-month tenor in effect on such day plus 1% and (b) the applicable margin. The Adjusted Term SOFR is equal to the sum of (a) the Term SOFR rate (as defined in our credit agreement amendment) for such period plus (b) the Term SOFR Adjustment of 0.1% plus (c) the applicable margin. The applicable margin varies from 2.25% to 3.75% on 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 September 30, 2022, the applicable margins on our borrowings were 2.00% for alternate base rate borrowings and 3.00% for Term SOFR borrowings based on our leverage ratio.

•Letter of credit fee rates range from 2.25% to 3.75% based on our leverage ratio as computed under the credit agreement and can fluctuate quarterly. At September 30, 2022, our letter of credit rate was 3.00%.

•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 September 30, 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.

At September 30, 2022, we had $120.2 million outstanding under our Revolving Loan, with $11.3 million of the borrowed amount designated as a loan under the inventory sublimit. Our credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which $4.5 million was outstanding at September 30, 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 September 30, 2022 was $525.3 million, subject to compliance with covenants. Our credit agreement does not include a “borrowing base” limitation except with respect to our inventory loans.

Alkali Senior Secured Notes Issuance and Related Transactions

On May 17, 2022, Genesis Energy, L.P., through its newly created wholly-owned unrestricted subsidiary, GA ORRI, LLC (“GA ORRI”), issued $425 million principal amount of our 5.875% senior secured notes due 2042 (the “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 on the last day of each quarter with the initial interest payment made 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 $49.9 million are due within the next five years, with the remaining quarterly principal repayments due thereafter through March 31, 2042. We are required to maintain a certain level of cash in a liquidity reserve account (owned by GA ORRI) to be held as collateral for future interest and principal payments as calculated and described in the agreement governing the Alkali senior secured notes. As of September 30, 2022 our liquidity reserve account had a balance of $18.6 million, which is classified as “Restricted cash” on the Unaudited Condensed Consolidated Balance Sheet. The issuance generated net proceeds of $408 million, net of the issuance discount of $17 million. We used a portion of the net proceeds 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 under our credit agreement as well as fund our liquidity reserve account.

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 credit agreement. We also designated GA ORRI and GA ORRI Holdings as unrestricted subsidiaries under the indentures governing our senior unsecured notes. On May 17, we also reclassified the subsidiaries originally held by our Alkali Business as restricted subsidiaries under our credit agreement and under the indentures governing our 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”). 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”) (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 debt issuance costs, which is recorded in “Other income (expense)” in our Unaudited Condensed Consolidated Statements of Operations for the nine months ended September 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 credit agreement.

During 2022, we repurchased certain of our senior unsecured notes on the open market and recorded cancellation of debt income of $3.9 million and $8.6 million for the three and nine months ended September 30, 2022, respectively. These are recorded within “Other income (expense)” in our Unaudited Consolidated Statements of Operations.

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 current and future 100% owned domestic subsidiaries (the “Guarantor Subsidiaries”), except GA ORRI and GA ORRI Holdings, and certain other subsidiaries. The 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. 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

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Partners' Capital, Mezzanine Capital and Distributions

9 Months Ended

Sep. 30, 2022

Equity [Abstract]

Partners' Capital, Mezzanine Capital and Distributions

Partners’ Capital, Mezzanine Capital and Distributions

At September 30, 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 September 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 2021 and 2022:

Distribution For	Date Paid		Per Unit Amount		Total Amount
2021
1st Quarter	May 14, 2021		$	0.15	$	18,387
2nd Quarter	August 13, 2021		$	0.15	$	18,387
3rd Quarter	November 12, 2021		$	0.15	$	18,387
4th Quarter	February 14, 2022		$	0.15	$	18,387
2022
1st Quarter	May 13, 2022		$	0.15	$	18,387
2nd Quarter	August 12, 2022		$	0.15	$	18,387
3rd Quarter	November 14, 2022	(1)	$	0.15	$	18,387

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

Class A Convertible Preferred Units

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. We initially recognized our Class A Convertible Preferred Units at their issuance date fair value, net of issuance costs, as they were not redeemable and we did not have plans or expect any events that constitute a change of control in our partnership agreement. Additionally, our Class A Convertible Preferred Units contains a distribution Rate Reset Election (as defined in Note 15), which was elected by the holders of the Class A Convertible Preferred Units on September 29, 2022 (the “election date”). From the date of issuance through the election date, this distribution rate reset was bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period in “Other long-term liabilities” in our Unaudited Condensed Consolidated Balance Sheets. As of the election date, the feature within the Class A Convertible Preferred Units that required bifurcation no longer existed and we have adjusted the carrying value of the Class A Convertible Preferred Units to include the fair value of the previously bifurcated amount at the election date. Refer to Note 15 and Note 16 for additional discussion.

As of September 30, 2022, we will not be required to further 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.

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 $56.1 million for the three and nine months ended September 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		$	0.7374	$	18,684
3rd Quarter	November 14, 2022	(1)	$	0.7374	$	18,684

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

As a result of the one-time Rate Reset Election made by the holders of the Class A Convertible Preferred Units on the election date, the annual distribution rate for the Class A Convertible Preferred Units increased from 8.75% to 11.24%, applicable for future quarterly distributions declared and payable, beginning with the quarter ended December 31, 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”) and a Securities Purchase Agreement (the “Securities Purchase Agreement”) whereby certain investment fund entities affiliated with Blackstone Alternative Credit Advisors LP, formerly known as “GSO Capital Partners LP” (collectively “BXC”) purchased $55.0 million (or 55,000 Alkali Holdings preferred units) and committed to purchase up to $350.0 million of Alkali Holdings preferred units, 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 utilized the net proceeds received from the preferred units to fund a portion of the anticipated cost of expansion of the Granger facility (the “Granger Optimization Project” or “GOP”).

On April 14, 2020, we entered into an amendment to our agreements with BXC to, among other things, extend the construction timeline of the GOP by one year, which we currently anticipate completing in the third quarter of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to 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 BXC was increased to, subject to compliance with the covenants contained in the agreements with BXC, up to $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 September 30, 2022, there were no Alkali Holdings preferred units outstanding.

Accounting for Redeemable Noncontrolling Interests

Classification

Prior to the Redemption Date, the Alkali Holdings preferred units issued and outstanding 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.

    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 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 was the IRR measure accreted using the effective interest method to the redemption value as of 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 Income Attributable to Genesis Energy, L.P. for the nine months ended September 30, 2022 includes $30.4 million of adjustments, of which $10.0 million was allocated to the paid-in-kind (“PIK”) distributions on the outstanding Alkali Holdings preferred units,$1.9 million, was attributable to redemption accretion value adjustments, and $18.5 million was attributable to 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 nine months ended September 30, 2021 includes $7.1 million and $17.7 million of adjustments, respectively, of which $5.9 million and $14.9 million, respectively, was allocated to the PIK distributions and $1.2 million and $2.8 million, respectively, was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended September 30, 2022 in-kind to our Alkali Holdings preferred unitholders.

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

Balance as of December 31, 2021	$	259,568
Issuance of preferred units, net of issuance costs(1)	5,249
PIK distribution	9,993
Redemption accretion	1,908
Tax distributions(1)	(6,631)
Adjustment to Base Preferred Return Amount	18,542
Redemption of preferred units on May 17, 2022	(288,629)
Balance as of September 30, 2022	$	—

(1)During the nine months ended September 30, 2022, we issued 5,356 Alkali Holdings preferred units to BXC to satisfy the Company’s obligation to pay tax distributions.

Noncontrolling Interests

On November 17, 2021, we, 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 its associated assets. We also own an 80% membership interest in Independence Hub, LLC. On April 29, 2022, we entered into an agreement to sell the Independence Hub platform to a producer group in the Gulf of Mexico for gross proceeds of $40.0 million, of which $8.0 million, or 20%, was attributable and was paid to our noncontrolling interest holders. For the nine months ended September 30, 2022, we recognized a gain of $40.0 million recorded in “Gain on sale of asset” on the Unaudited Condensed Consolidated Statement of Operations, of which $8.0 million, or 20%, is attributable to our noncontrolling interest holders, as the 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.

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Net Loss Per Common Unit

9 Months Ended

Sep. 30, 2022

Net Income per Common Unit [Abstract]

Net Loss Per Common Unit

Net Loss Per Common Unit

Basic net income (loss) per common unit is computed by dividing 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, 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 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 nine months ended September 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 income (loss) attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net loss per common unit (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
Net loss attributable to common unitholders	$	(15,299)	$	(39,583)	$	(22,570)	$	(152,857)
Weighted average outstanding units	122,579		122,579		122,579		122,579
Basic and diluted net loss per common unit	$	(0.12)	$	(0.32)	$	(0.18)	$	(1.25)

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Business Segment Information

9 Months Ended

Sep. 30, 2022

Segment Reporting [Abstract]

Business Segment Information

Business Segment Information

We currently manage our businesses through four 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 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 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 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.

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Transactions with Related Parties

9 Months Ended

Sep. 30, 2022

Related Party Transactions [Abstract]

Transactions with Related Parties

Transactions with Related Parties

The transactions with related parties were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues:
Revenues from services and fees to Poseidon(1)	$	3,854	$	3,193	$	10,952	$	10,221
Revenues from product sales to ANSAC	109,046		61,651		294,556		200,935
Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	495	$	495
Charges for services from Poseidon(1)	268		242		777		720
Charges for services from ANSAC	2,596		400		5,781		1,097

(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 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 nine months ended September 30, 2022 include $2.4 million and $7.3 million, respectively, of fees we earned through the provision of services under that agreement. Our revenues for the three and nine months ended September 30, 2021 include $2.4 million and $7.1 million, respectively, of fees we earned through the provision of services under that agreement. At September 30, 2022 and December 31, 2021, Poseidon owed us $2.0 million and $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”), 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 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 September 30, 2022, such amount is not material to us.

Net Sales to ANSAC were $109.0 million and $294.6 million, respectively, during the three and nine months ended September 30, 2022, and were $61.7 million and $200.9 million, respectively, during the three and nine months ended September 30, 2021. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $2.6 million and $5.8 million, respectively, during the three and nine months ended September 30, 2022, and were $0.4 million and $1.1 million, respectively, during the three and nine months ended September 30, 2021.

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

	September 30,		December 31,
	2022		2021
Accounts receivable - trade, net:
ANSAC	$	103,582	$	64,799
Accounts payable - trade:
ANSAC	$	2,596	$	116

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Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2022

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

Supplemental Cash Flow Information

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

	Nine Months Ended September 30,
	2022		2021
(Increase) decrease in:
Accounts receivable	$	(170,635)	$	15,487
Inventories	(12,677)		11,108
Deferred charges	47,191		20,362
Other current assets	(4,717)		(10,335)
Increase (decrease) in:
Accounts payable	109,687		(50,361)
Accrued liabilities	(17,425)		20,196
Net changes in components of operating assets and liabilities	$	(48,576)	$	6,457

Payments of interest and commitment fees were $189.2 million and $154.4 million for the nine months ended September 30, 2022 and September 30, 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 and July during 2022. The first interest payment made on our 2027 Notes was in July 2021.

We capitalized interest of $11.2 million and $2.3 million during the nine months ended September 30, 2022 and September 30, 2021, respectively. The increase in capitalized interest is due to our growth capital expenditures associated with our GOP (Note 10) and our offshore growth capital projects.

At September 30, 2022 and September 30, 2021, we had incurred liabilities for fixed and intangible asset additions totaling $67.6 million and $44.9 million, respectively, that had not been paid at the end of the 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 amounts as of September 30, 2022 primarily relate to the capital expenditures associated with our GOP (Note 10) and offshore growth capital projects.

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Derivatives

9 Months Ended

Sep. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

Derivatives

Commodity Derivatives

We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (exchange-traded futures, options and 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; therefore, we do not designate derivative contracts utilized to limit our price risk related to 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 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 exchange requirements, we fund the margin associated with our exchange-traded commodity derivative contracts. The amount of the margin is adjusted daily based on the fair value of the commodity derivative contracts. Margin requirements are intended to mitigate a party’s exposure to market volatility and counterparty credit risk. We offset fair value amounts recorded for our exchange-traded derivative contracts against required margin funding in “Current Assets - Other” in our Unaudited Condensed Consolidated Balance Sheets.

Additionally, we 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, 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 natural gas derivative contracts as increases or decreases within “Sodium minerals and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations.

At September 30, 2022, we 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)	104		—
Weighted average contract price per Bbl	$	88.81	$	—
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 Bbls)	102		96
Weighted average contract price per Bbl	$	85.02	$	84.56
Natural gas swaps:
Contract volumes (10,000 MMBtu)	—		367
Weighted average price differential per MMBtu	$	—	$	(0.30)
Natural gas futures:
Contract volumes (10,000 MMBtu)	66		433
Weighted average contract price per MMBtu	$	7.50	$	5.26
Petroleum products (#6 fuel oil) futures:
Contract volumes (1,000 Bbls)	120		70
Weighted average contract price per Bbl	$	61.81	$	60.99
Natural gas options:
Contract volumes (10,000 MMBtu)	109		20
Weighted average premium received/paid	$	0.59	$	0.07

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 balance required to maintain our exchange-traded derivative contracts also affect cash flows from operating activities.

The following tables reflect the estimated fair value position of our derivatives at September 30, 2022 and December 31, 2021:

Fair Value of Derivative Assets and Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2022		December 31, 2021
Asset Derivatives:
Natural Gas Swap (undesignated hedge)	Current Assets - Other	221		1,867
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized assets	Current Assets - Other	$	3,688	$	310
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(1,622)		(310)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	2,066	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized assets	Current Assets - Other	$	1,599	$	49
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(557)		(49)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	1,042	$	—
Liability Derivatives:
Preferred Distribution Rate Reset Election(2)	Other long-term liabilities	—		(83,210)
Natural Gas Swap (undesignated hedge)	Current Liabilities -Accrued Liabilities	(808)		(608)
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(1,622)	$	(2,380)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	1,622		2,380
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets		$	—	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(557)	$	(209)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	557		209
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 Assets - Other”.

(2)Refer to Note 10, Note 16 and below 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 our cash 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 September 30, 2022, we had a net broker receivable of approximately $5.8 million (consisting of initial margin of $5.3 million increased by $0.5 million variation margin).  As of December 31, 2021, we had a net broker receivable of

approximately $2.9 million (consisting of initial margin of $2.1 million increased by $0.8 million of variation margin).  At September 30, 2022 and December 31, 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. 

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 distribution amount (a “Rate Reset 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 Sheets. Corresponding changes in fair value are recognized in “Other income (expense)” in our Unaudited Condensed Consolidated Statement of Operations.

On the election date, the holders of the Class A Convertible Preferred Units elected to reset the rate to 11.24%, the sum of the three-month LIBOR of 3.74% plus 750 basis points. The fair value of this embedded derivative at the time of election was a liability of $101.8 million. As of the election date, the feature within the Class A Convertible Preferred Units that required bifurcation no longer existed and we have adjusted the carrying value of the Class A Convertible Preferred Units to include the fair value of the previously bifurcated amount at the election date. 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
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	2,085	$	(285)	$	1,549	$	(7,745)
Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	7,138		(171)		15,418		(5,871)
Total commodity derivatives		$	9,223	$	(456)	$	16,967	$	(13,616)
Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	(489)	$	(55)	$	(2,181)	$	(92)
Preferred Distribution Rate Reset Election	Other income (expense)	$	(24,977)	$	1,740	$	(18,584)	$	(31,042)

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Fair-Value Measurements

9 Months Ended

Sep. 30, 2022

Fair Value Disclosures [Abstract]

Fair-Value Measurements

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.

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 September 30, 2022 and December 31, 2021. 

	September 30, 2022						December 31, 2021
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Commodity derivatives:
Assets	$	5,287	$	221	$	—	$	359	$	1,867	$	—
Liabilities	$	(2,179)	$	(808)	$	—	$	(2,589)	$	(608)	$	—
Preferred Distribution Rate Reset Election	$	—	$	—	$	—	$	—	$	—	$	(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:

Balance as of December 31, 2021	$	(83,210)
Net loss for the period included in earnings	(18,584)
Reclassification to Mezzanine Equity	101,794
Balance as of September 30, 2022	$	—

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 September 30, 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 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 September 29, 2022, which represents the final valuation date of the embedded derivative due to the Rate Reset Election. Due primarily to the election of the rate reset increasing the annual distribution rate from 8.75% to 11.24%, we recorded an unrealized loss of $25.0 million and $18.6 million for the three and nine months ended September 30, 2022, respectively. Due to an increase in our discount yield compared to the preceding quarter, we recorded an unrealized gain of $1.7 million for the three months ended September 30, 2021; however, an overall decrease in our discount yield compared to December 31, 2020 resulted in an unrealized loss of $31.0 million for the nine months ended September 30, 2021. These effects are all recorded within “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 September 30, 2022 our senior unsecured notes had a carrying value of approximately $2.9 billion and a fair value of approximately $2.6 billion compared to a carrying value and fair value of approximately $3.0 billion at December 31, 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.

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Commitments and Contingencies	9 Months Ended
	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and ContingenciesWe 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.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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Subsequent Events	9 Months Ended
	Sep. 30, 2022
Subsequent Events [Abstract]
Subsequent Events	Subsequent EventsOn April 29, 2022, we entered into an agreement to sell our 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 paid to our noncontrolling interest holders. We will recognize a gain of approximately $40 million, of which $8 million, or 20%, is attributable to our noncontrolling interest holders, in the second quarter 2022, as the platform asset sold had essentially no book value at the time of the sale.

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Recent Accounting Developments (Policies)

9 Months Ended

Sep. 30, 2022

Accounting Policies [Abstract]

Basis of Presentation and Consolidation

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”). 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”) 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, 2021 (our “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.

Recent and Proposed Accounting Pronouncements

Recent and Proposed Accounting PronouncementsIn March 2020, the 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 anticipated discontinuation of the 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 replacement of a 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 among other things, replaced our existing LIBOR rate based borrowings with the Term SOFR rate, which is based on the Secured Overnight Financing Rate (“SOFR”) borrowings. The impact to our senior secured credit facility and related interest expense upon

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Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2022

Revenue Recognition [Abstract]

Schedule of Disaggregation of Revenue

The following tables reflect the disaggregation of our revenues by major category for the nine months ended September 30, 2022 and 2021, respectively:

	Nine Months Ended September 30, 2022
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	239,958	$	—	$	209,889	$	54,280	$	504,127
Product Sales	—		837,335		—		653,830		1,491,165
Refinery Services	—		79,628		—		—		79,628
	$	239,958	$	916,963	$	209,889	$	708,110	$	2,074,920

	Nine Months Ended September 30, 2021
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	207,084	$	—	$	136,673	$	69,173	$	412,930
Product Sales	—		628,209		—		428,940		1,057,149
Refinery Services	—		73,816		—		—		73,816
	$	207,084	$	702,025	$	136,673	$	498,113	$	1,543,895

Schedule of Contract Asset and Liabilities Balances Activity

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

	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 September 30, 2022	—		16,662		35,602

Schedule of Revenue Expected to be Recognized in Future Periods

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 2022	$	19,314	$	1,800
2023	67,941		7,200
2024	60,970		1,800
2025	64,292		—
2026	45,834		—
Thereafter	57,748		—
Total	$	316,099	$	10,800

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Inventories (Tables)

9 Months Ended

Sep. 30, 2022

Inventory Disclosure [Abstract]

Schedule of Major Components of Inventories

The major components of inventories were as follows:

	September 30, 2022		December 31, 2021
Petroleum products	$	3,054	$	998
Crude oil	15,451		11,834
Caustic soda	11,636		5,690
NaHS	18,236		17,040
Raw materials - Alkali operations	6,672		7,599
Work-in-process - Alkali operations	8,299		7,496
Finished goods, net - Alkali operations	14,281		13,681
Materials and supplies, net - Alkali operations	15,278		13,620
Total	$	92,907	$	77,958

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2022

Fixed Assets And Asset Retirement Obligations [Abstract]

Schedule of Fixed Assets

Fixed assets consisted of the following:

	September 30, 2022		December 31, 2021
Crude oil and natural gas pipelines and related assets	$	2,840,829	$	2,839,443
Alkali facilities, machinery and equipment	688,569		670,880
Onshore facilities, machinery and equipment	269,249		269,245
Transportation equipment	22,032		21,106
Marine vessels	1,013,713		1,018,284
Land, buildings and improvements	229,202		227,540
Office equipment, furniture and fixtures	27,066		23,965
Construction in progress	599,802		350,137
Other	41,168		43,440
Fixed assets, at cost	5,731,630		5,464,040
Less: Accumulated depreciation	(1,711,306)		(1,551,855)
Net fixed assets	$	4,020,324	$	3,912,185

Schedule of Mineral Leaseholds

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

	September 30, 2022		December 31, 2021
Mineral leaseholds	$	566,019	$	566,019
Less: Accumulated depletion	(19,844)		(17,014)
Mineral leaseholds, net of accumulated depletion	$	546,175	$	549,005

Schedule of Depreciation and Depletion Expense

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Depreciation expense	$	70,328	$	63,482	$	206,111	$	190,332
Depletion expense	896		959		2,830		2,575

Schedule of Change in Asset Retirement Obligation

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

ARO liability balance, December 31, 2021	$	220,906
Accretion expense	10,175
Changes in estimate	3,189
Settlements	(12,267)
ARO liability balance, September 30, 2022	$	222,003

Schedule of Forecast of Accretion Expense of Asset Retirement Obligations

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

Remainder of	2022	$	2,909
	2023	$	10,640
	2024	$	9,827
	2025	$	10,532
	2026	$	8,281

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Equity Investees (Tables)

9 Months Ended

Sep. 30, 2022

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Consolidated Financial Statements Related to Equity Investees

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Genesis’ share of operating earnings	$	16,802	$	14,174	$	50,950	$	56,801
Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)		(3,873)		(10,698)		(11,618)
Net equity in earnings	$	13,236	$	10,301	$	40,252	$	45,183
Distributions received(1)	$	18,483	$	17,443	$	56,233	$	68,873

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

Schedule of Balance Sheet Information for Equity Investees

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):

	September 30, 2022		December 31, 2021
BALANCE SHEETS DATA:
Assets
Current assets	$	27,448	$	17,827
Fixed assets, net	150,416		160,379
Other assets	11,958		6,186
Total assets	$	189,822	$	184,392
Liabilities and equity
Current liabilities	$	12,667	$	7,668
Other liabilities	234,401		231,970
Equity (Deficit)	(57,246)		(55,246)
Total liabilities and equity	$	189,822	$	184,392

Schedule Of Operations For Equity Investees

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
STATEMENTS OF OPERATIONS DATA:
Revenues	$	38,322	$	27,262	$	104,891	$	103,432
Operating income	$	27,731	$	18,762	$	75,540	$	75,559
Net income	$	25,502	$	17,718	$	70,850	$	72,473

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Intangible Assets (Tables)

9 Months Ended

Sep. 30, 2022

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Schedule of Components of Intangible Assets

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

	September 30, 2022						December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Marine contract intangibles	$	800	$	634	$	166	$	800	$	607	$	193
Offshore pipeline contract intangibles	158,101		59,635		98,466		158,101		53,394		104,707
Other	45,811		17,242		28,569		37,933		15,770		22,163
Total	$	204,712	$	77,511	$	127,201	$	196,834	$	69,771	$	127,063

Schedule of Amortization Expense

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Amortization of intangible assets	$	2,575	$	2,575	$	7,740	$	7,755

Schedule of Expected Amortization Expense

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

Remainder of	2022	$	3,132
	2023	$	12,302
	2024	$	11,937
	2025	$	11,712
	2026	$	11,412

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Debt (Tables)

9 Months Ended

Sep. 30, 2022

Debt Disclosure [Abstract]

Schedule of Debt

Our obligations under debt arrangements consisted of the following:

	September 30, 2022						December 31, 2021
	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)	$	120,200	$	—	$	120,200	$	49,000	$	—	$	49,000
5.625% senior unsecured notes due 2024	341,135		1,464		339,671		341,135		2,106		339,029
6.500% senior unsecured notes due 2025	534,834		3,562		531,272		534,834		4,452		530,382
6.250% senior unsecured notes due 2026	339,310		2,664		336,646		359,799		3,410		356,389
8.000% senior unsecured notes due 2027	981,245		5,325		975,920		1,000,000		6,592		993,408
7.750% senior unsecured notes due 2028	679,360		7,995		671,365		720,975		9,678		711,297
5.875% Alkali senior secured notes due 2042	425,000		22,746		402,254		—		—		—
Total long-term debt	$	3,421,084	$	43,756	$	3,377,328	$	3,005,743	$	26,238	$	2,979,505

(1)    Unamortized debt issuance costs associated with our Revolving Loan, as defined below (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were $3.1 million and $4.7 million as of September 30, 2022 and December 31, 2021, respectively.

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Partners' Capital, Mezzanine Capital and Distributions (Tables)

9 Months Ended

Sep. 30, 2022

Equity [Abstract]

Schedule of Paid Distributions

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

Distribution For	Date Paid		Per Unit Amount		Total Amount
2021
1st Quarter	May 14, 2021		$	0.15	$	18,387
2nd Quarter	August 13, 2021		$	0.15	$	18,387
3rd Quarter	November 12, 2021		$	0.15	$	18,387
4th Quarter	February 14, 2022		$	0.15	$	18,387
2022
1st Quarter	May 13, 2022		$	0.15	$	18,387
2nd Quarter	August 12, 2022		$	0.15	$	18,387
3rd Quarter	November 14, 2022	(1)	$	0.15	$	18,387

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

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		$	0.7374	$	18,684
3rd Quarter	November 14, 2022	(1)	$	0.7374	$	18,684

(1)This distribution was declared on October 10, 2022 and will be paid to unitholders of record as of October 31, 2022.

Schedule of Changes in Redeemable Noncontrolling Interest

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

Balance as of December 31, 2021	$	259,568
Issuance of preferred units, net of issuance costs(1)	5,249
PIK distribution	9,993
Redemption accretion	1,908
Tax distributions(1)	(6,631)
Adjustment to Base Preferred Return Amount	18,542
Redemption of preferred units on May 17, 2022	(288,629)
Balance as of September 30, 2022	$	—

(1)During the nine months ended September 30, 2022, we issued 5,356 Alkali Holdings preferred units to BXC to satisfy the Company’s obligation to pay tax distributions.

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Net Loss Per Common Unit (Tables)

9 Months Ended

Sep. 30, 2022

Net Income per Common Unit [Abstract]

Schedule of Computation of Earnings Per Share, Basic and Diluted

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

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Net income (loss) attributable to Genesis Energy, L.P.	$	3,385	$	(20,899)	$	33,482	$	(96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
Net loss attributable to common unitholders	$	(15,299)	$	(39,583)	$	(22,570)	$	(152,857)
Weighted average outstanding units	122,579		122,579		122,579		122,579
Basic and diluted net loss per common unit	$	(0.12)	$	(0.32)	$	(0.18)	$	(1.25)

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Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2022

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

Segment information for the periods presented below was as follows:

	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Onshore Facilities & Transportation		Marine Transportation		Total
Three Months Ended September 30, 2022
Segment Margin(1)	$	91,402	$	80,067	$	9,442	$	15,279	$	196,190
Capital expenditures(2)	$	86,893	$	49,452	$	848	$	14,575	$	151,768
Revenues:
External customers	$	89,805	$	315,334	$	238,483	$	77,626	$	721,248
Intersegment(3)	—		(2,653)		2,484		169		—
Total revenues of reportable segments	$	89,805	$	312,681	$	240,967	$	77,795	$	721,248
Three Months Ended September 30, 2021
Segment Margin(1)	$	76,045	$	39,649	$	29,145	$	9,023	$	153,862
Capital expenditures(2)	$	3,819	$	67,583	$	929	$	6,886	$	79,217
Revenues:
External customers	$	69,479	$	240,048	$	161,296	$	47,998	$	518,821
Intersegment(3)	—		(2,397)		1,679		718		—
Total revenues of reportable segments	$	69,479	$	237,651	$	162,975	$	48,716	$	518,821
Nine Months Ended September 30, 2022
Segment Margin(1)	$	281,286	$	219,143	$	27,496	$	44,989	$	572,914
Capital expenditures(2)	$	166,703	$	114,698	$	3,365	$	28,704	$	313,470
Revenues:
External customers	$	239,958	$	924,534	$	700,909	$	209,519	$	2,074,920
Intersegment(3)	—		(7,571)		7,201		370		—
Total revenues of reportable segments	$	239,958	$	916,963	$	708,110	$	209,889	$	2,074,920
Nine Months Ended September 30, 2021
Segment Margin(1)	$	243,420	$	121,563	$	72,512	$	24,600	$	462,095
Capital expenditures(2)	$	34,768	$	158,181	$	4,515	$	29,757	$	227,221
Revenues:
External customers	$	207,084	$	708,612	$	493,852	$	134,347	$	1,543,895
Intersegment(3)	—		(6,587)		4,261		2,326		—
Total revenues of reportable segments	$	207,084	$	702,025	$	498,113	$	136,673	$	1,543,895

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

(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.

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

Total assets by reportable segment were as follows:

	September 30, 2022		December 31, 2021
Offshore pipeline transportation	$	2,214,924	$	2,103,140
Sodium minerals and sulfur services	2,230,163		2,132,588
Onshore facilities and transportation	974,464		923,064
Marine transportation	692,303		703,030
Other assets	57,685		43,979
Total consolidated assets	$	6,169,539	$	5,905,801

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Transactions with Related Parties (Tables)

9 Months Ended

Sep. 30, 2022

Related Party Transactions [Abstract]

Schedule Of Transactions with Related Parties

The transactions with related parties were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2022		2021		2022		2021
Revenues:
Revenues from services and fees to Poseidon(1)	$	3,854	$	3,193	$	10,952	$	10,221
Revenues from product sales to ANSAC	109,046		61,651		294,556		200,935
Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	495	$	495
Charges for services from Poseidon(1)	268		242		777		720
Charges for services from ANSAC	2,596		400		5,781		1,097

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

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

	September 30,		December 31,
	2022		2021
Accounts receivable - trade, net:
ANSAC	$	103,582	$	64,799
Accounts payable - trade:
ANSAC	$	2,596	$	116

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Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2022

Supplemental Cash Flow Elements [Abstract]

Net Changes In Components of Operating Assets and Liabilities

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

	Nine Months Ended September 30,
	2022		2021
(Increase) decrease in:
Accounts receivable	$	(170,635)	$	15,487
Inventories	(12,677)		11,108
Deferred charges	47,191		20,362
Other current assets	(4,717)		(10,335)
Increase (decrease) in:
Accounts payable	109,687		(50,361)
Accrued liabilities	(17,425)		20,196
Net changes in components of operating assets and liabilities	$	(48,576)	$	6,457

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Derivatives (Tables)

9 Months Ended

Sep. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments

At September 30, 2022, we 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)	104		—
Weighted average contract price per Bbl	$	88.81	$	—
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 Bbls)	102		96
Weighted average contract price per Bbl	$	85.02	$	84.56
Natural gas swaps:
Contract volumes (10,000 MMBtu)	—		367
Weighted average price differential per MMBtu	$	—	$	(0.30)
Natural gas futures:
Contract volumes (10,000 MMBtu)	66		433
Weighted average contract price per MMBtu	$	7.50	$	5.26
Petroleum products (#6 fuel oil) futures:
Contract volumes (1,000 Bbls)	120		70
Weighted average contract price per Bbl	$	61.81	$	60.99
Natural gas options:
Contract volumes (10,000 MMBtu)	109		20
Weighted average premium received/paid	$	0.59	$	0.07

Schedule of Fair Value of Derivative Assets and Liabilities

The following tables reflect the estimated fair value position of our derivatives at September 30, 2022 and December 31, 2021:

Fair Value of Derivative Assets and Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2022		December 31, 2021
Asset Derivatives:
Natural Gas Swap (undesignated hedge)	Current Assets - Other	221		1,867
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized assets	Current Assets - Other	$	3,688	$	310
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(1,622)		(310)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	2,066	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized assets	Current Assets - Other	$	1,599	$	49
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(557)		(49)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets		$	1,042	$	—
Liability Derivatives:
Preferred Distribution Rate Reset Election(2)	Other long-term liabilities	—		(83,210)
Natural Gas Swap (undesignated hedge)	Current Liabilities -Accrued Liabilities	(808)		(608)
Commodity derivatives - futures and put and call options (undesignated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(1,622)	$	(2,380)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	1,622		2,380
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets		$	—	$	—
Commodity derivatives - futures (designated hedges):
Gross amount of recognized liabilities	Current Assets - Other(1)	$	(557)	$	(209)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other(1)	557		209
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 Assets - Other”.

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

Schedule of Effect on Operating Results

Effect on Operating Results 

		Amount of Gain (Loss) Recognized in Income
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2022		2021		2022		2021
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	2,085	$	(285)	$	1,549	$	(7,745)
Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	7,138		(171)		15,418		(5,871)
Total commodity derivatives		$	9,223	$	(456)	$	16,967	$	(13,616)
Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	(489)	$	(55)	$	(2,181)	$	(92)
Preferred Distribution Rate Reset Election	Other income (expense)	$	(24,977)	$	1,740	$	(18,584)	$	(31,042)

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Fair-Value Measurements (Tables)

9 Months Ended

Sep. 30, 2022

Fair Value Disclosures [Abstract]

Schedule of Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels

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 September 30, 2022 and December 31, 2021. 

	September 30, 2022						December 31, 2021
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Commodity derivatives:
Assets	$	5,287	$	221	$	—	$	359	$	1,867	$	—
Liabilities	$	(2,179)	$	(808)	$	—	$	(2,589)	$	(608)	$	—
Preferred Distribution Rate Reset Election	$	—	$	—	$	—	$	—	$	—	$	(83,210)

Schedule of Reconciliation of Changes in Fair Value of Derivatives Classified as Level 3

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

Balance as of December 31, 2021	$	(83,210)
Net loss for the period included in earnings	(18,584)
Reclassification to Mezzanine Equity	101,794
Balance as of September 30, 2022	$	—

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Organization and Basis of Presentation and Consolidation (Details)	9 Months Ended
	Sep. 30, 2022 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

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Revenue Recognition (Disaggregated Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Total revenues	$ 721,248	$ 518,821	$ 2,074,920	$ 1,543,895
Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	187,777	144,798	504,127	412,930
Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	511,410	347,369	1,491,165	1,057,149
Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	22,061	26,654	79,628	73,816
Offshore Pipeline Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	89,805	69,479	239,958	207,084
Offshore Pipeline Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	89,805	69,479	239,958	207,084
Offshore Pipeline Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Offshore Pipeline Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Sodium Minerals and Sulfur Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	312,681	237,651	916,963	702,025
Sodium Minerals and Sulfur Services [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Sodium Minerals and Sulfur Services [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	290,620	210,997	837,335	628,209
Sodium Minerals and Sulfur Services [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	22,061	26,654	79,628	73,816
Marine Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	77,795	48,716	209,889	136,673
Marine Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	77,795	48,716	209,889	136,673
Marine Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Marine Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Onshore Facilities and Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	240,967	162,975	708,110	498,113
Onshore Facilities and Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	20,177	26,603	54,280	69,173
Onshore Facilities and Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	220,790	136,372	653,830	428,940
Onshore Facilities and Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	$ 0	$ 0	$ 0	$ 0

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Revenue Recognition (Contract Assets and Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Contract Liability, Accrued Liabilities	$ 16,662	$ 2,619
Contract Assets, Current Assets-Other	0	13,563
Contract Liabilities, Other Long-Term Liabilities	$ 35,602	$ 19,028

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Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in Thousands	Sep. 30, 2022 USD ($)
Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 316,099
Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	10,800
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 19,314
Revenue expected timing of satisfaction period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 1,800
Revenue expected timing of satisfaction period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 67,941
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 7,200
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 60,970
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 1,800
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 64,292
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 45,834
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 57,748
Revenue expected timing of satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period

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Lease Accounting (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Marine Transportation [Member] | M/T American Phoenix [Member]
Lessor, Lease, Description [Line Items]
Operating lease income	$ 1,800	$ 4,100	$ 10,500	$ 11,400

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Inventories (Major Components of Inventories) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Petroleum products	$ 3,054	$ 998
Crude oil	15,451	11,834
Caustic soda	11,636	5,690
NaHS	18,236	17,040
Raw materials - Alkali operations	6,672	7,599
Work-in-process - Alkali operations	8,299	7,496
Finished goods, net - Alkali operations	14,281	13,681
Materials and supplies, net - Alkali operations	15,278	13,620
Total	$ 92,907	$ 77,958

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Inventories (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Inventory write-down	$ 2.4	$ 2.0

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Fixed Assets, Net) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 5,731,630	$ 5,464,040
Less: Accumulated depreciation	(1,711,306)	(1,551,855)
Net fixed assets	4,020,324	3,912,185
Crude oil and natural gas pipelines and related assets
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	2,840,829	2,839,443
Onshore facilities, machinery and equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	269,249	269,245
Onshore facilities, machinery and equipment | Alkali Business
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	688,569	670,880
Transportation equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	22,032	21,106
Marine vessels
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	1,013,713	1,018,284
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	229,202	227,540
Office equipment, furniture and fixtures
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	27,066	23,965
Construction in progress
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	599,802	350,137
Other
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 41,168	$ 43,440

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Mineral Leaseholds) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Mineral leaseholds	$ 566,019	$ 566,019
Less: Accumulated depletion	(19,844)	(17,014)
Mineral leaseholds, net of accumulated depletion	$ 546,175	$ 549,005

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 70,328	$ 63,482	$ 206,111	$ 190,332
Depletion expense	$ 896	$ 959	$ 2,830	$ 2,575

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Asset Retirement Obligation Rollforward) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2022 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2021	$ 220,906
Accretion expense	10,175
Changes in estimate	3,189
Settlements	(12,267)
ARO liability balance, September 30, 2022	$ 222,003

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 222,003	$ 220,906
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 28,800	$ 36,300

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Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Forecast of Accretion Expense) (Details) $ in Thousands	Sep. 30, 2022 USD ($)
Fixed Assets And Asset Retirement Obligations [Abstract]
Remainder of 2022	$ 2,909
2023	10,640
2024	9,827
2025	10,532
2026	$ 8,281

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Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 309.2	$ 319.9

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Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Equity Method Investments and Joint Ventures [Abstract]
Genesis’ share of operating earnings	$ 16,802	$ 14,174	$ 50,950	$ 56,801
Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)	(3,873)	(10,698)	(11,618)
Net equity in earnings	13,236	10,301	40,252	45,183
Distributions received	$ 18,483	$ 17,443	$ 56,233	$ 68,873

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Equity Investees (Schedule of Balance Sheet Information for Equity Investees) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Assets
Current assets	$ 726,430	$ 542,484
Fixed assets, net	4,020,324	3,912,185
Total assets	6,169,539	5,905,801
LIABILITIES AND CAPITAL
Current liabilities	645,317	496,939
Total liabilities and equity	6,169,539	5,905,801
Poseidon
Assets
Current assets	27,448	17,827
Fixed assets, net	150,416	160,379
Other assets	11,958	6,186
Total assets	189,822	184,392
LIABILITIES AND CAPITAL
Current liabilities	12,667	7,668
Other liabilities	234,401	231,970
Equity (Deficit)	(57,246)	(55,246)
Total liabilities and equity	$ 189,822	$ 184,392

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Equity Investees (Schedule of Operations for Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
INCOME STATEMENT DATA:
Revenues	$ 721,248	$ 518,821	$ 2,074,920	$ 1,543,895
Operating income	75,095	34,494	223,351	88,052
Net income	3,385	(20,899)	33,482	(96,805)
Poseidon
INCOME STATEMENT DATA:
Revenues	38,322	27,262	104,891	103,432
Operating income	27,731	18,762	75,540	75,559
Net income	$ 25,502	$ 17,718	$ 70,850	$ 72,473

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Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 204,712	$ 196,834
Accumulated Amortization	77,511	69,771
Carrying Value	127,201	127,063
Contract intangibles | Marine Transportation [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	800	800
Accumulated Amortization	634	607
Carrying Value	166	193
Contract intangibles | Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	158,101	158,101
Accumulated Amortization	59,635	53,394
Carrying Value	98,466	104,707
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	45,811	37,933
Accumulated Amortization	17,242	15,770
Carrying Value	$ 28,569	$ 22,163

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Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Amortization of intangible assets	$ 2,575	$ 2,575	$ 7,740	$ 7,755
Remainder of 2021	3,132		3,132
2023	12,302		12,302
2024	11,937		11,937
2025	11,712		11,712
2026	$ 11,412		$ 11,412

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Debt (Schedule of Obligations Under Debt Arrangements) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	May 17, 2022	Dec. 31, 2021	Dec. 17, 2020
Debt Instrument [Line Items]
Principal	$ 3,421,084		$ 3,005,743
Unamortized Premium, Discount and Debt Issuance Costs	43,756		26,238
Net Value	3,377,328		2,979,505
Credit Facility | Revolving Credit Facility | Revolving Loan
Debt Instrument [Line Items]
Principal	120,200		49,000
Unamortized Premium, Discount and Debt Issuance Costs	0		0
Net Value	120,200		49,000
Unamortized debt issuance costs	$ 3,100		$ 4,700
Senior Notes | 5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Interest rate	562.50%		562.50%
Principal	$ 341,135		$ 341,135
Unamortized Premium, Discount and Debt Issuance Costs	1,464		2,106
Net Value	$ 339,671		$ 339,029
Senior Notes | 6.500% senior unsecured notes due 2025
Debt Instrument [Line Items]
Interest rate	650.00%		650.00%
Principal	$ 534,834		$ 534,834
Unamortized Premium, Discount and Debt Issuance Costs	3,562		4,452
Net Value	$ 531,272		$ 530,382
Senior Notes | 6.250% senior unsecured notes due 2026
Debt Instrument [Line Items]
Interest rate	625.00%		625.00%
Principal	$ 339,310		$ 359,799
Unamortized Premium, Discount and Debt Issuance Costs	2,664		3,410
Net Value	$ 336,646		$ 356,389
Senior Notes | 8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Interest rate	800.00%		800.00%	8.00%
Principal	$ 981,245		$ 1,000,000
Unamortized Premium, Discount and Debt Issuance Costs	5,325		6,592
Net Value	$ 975,920		$ 993,408
Senior Notes | 7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Interest rate	775.00%		775.00%
Principal	$ 679,360		$ 720,975
Unamortized Premium, Discount and Debt Issuance Costs	7,995		9,678
Net Value	$ 671,365		711,297
Senior Notes | 5.875% Alkali senior secured notes due 2042
Debt Instrument [Line Items]
Interest rate	587.50%	5.875%
Principal	$ 425,000		0
Unamortized Premium, Discount and Debt Issuance Costs	22,746		0
Net Value	$ 402,254		$ 0

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Debt (Narrative) (Details)						3 Months Ended		9 Months Ended
	May 17, 2022 USD ($)	Nov. 16, 2021	Apr. 22, 2021 USD ($)	Jan. 19, 2021 USD ($)	Dec. 17, 2020 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)	Apr. 08, 2021 USD ($)
Debt Instrument [Line Items]
Repayment of senior unsecured notes								$ 72,241,000	$ 80,859,000
Loss on extinguishment of debt						$ (293,000)	$ 0	794,000	1,627,000
Cancelation of debt income						3,881,000	$ 0	8,619,000	$ 0
Principal						3,421,084,000		3,421,084,000		$ 3,005,743,000
Restricted cash						18,637,000		$ 18,637,000		5,005,000
Cameron Highway Oil Pipeline | Affiliated Entity
Debt Instrument [Line Items]
Sale Of Stock, Percentage Of Ownership Sold		0.36						0.36
Senior Notes | Guarantor Subsidiary | Genesis Energy, LLC | Genesis Finance Corporation
Debt Instrument [Line Items]
Guarantor obligations, current carrying value						2,900,000,000		$ 2,900,000,000
Percentage of equity interest								100.00%
Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity											$ 950,000,000
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage								3.00%
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Letter of credit, fee percentage								3.75%
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Letter of credit, fee percentage								2.25%
Revolving Loan | Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity											$ 650,000,000
Line of credit, unused capacity commitment fee percentage								0.50%
Credit facility, additional borrowing capacity						200,000,000		$ 200,000,000
Credit facility, amount borrowed						120,200,000		120,200,000
Letters of credit, outstanding amount						4,500,000		4,500,000
Line of Credit Facility, Remaining Borrowing Capacity						525,300,000		525,300,000
Principal						120,200,000		120,200,000		$ 49,000,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount borrowed						11,300,000		$ 11,300,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage								0.50%
Letters of credit, outstanding amount						100,000,000		$ 100,000,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage								0.30%
Revolving Loan | Credit Facility | Revolving Credit Facility | Federal Funds Effective Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								0.50%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								2.00%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								2.75%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								1.25%
Revolving Loan | Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								3.00%
Revolving Loan | Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								3.75%
Revolving Loan | Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Maximum | One-month Tenor
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								1.00%
Revolving Loan | Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Maximum | Term SOFR Adjustment
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								0.10%
Revolving Loan | Credit Facility | Revolving Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								2.25%
Term Loan | Credit Facility
Debt Instrument [Line Items]
Debt Instrument, Face Amount						$ 300,000,000		$ 300,000,000
8.000% senior unsecured notes due 2027 | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 250,000,000		$ 750,000,000
Interest rate					8.00%	800.00%		800.00%		800.00%
Proceeds from issuance of debt					$ 737,000,000
Debt premium percentage			103.75%
Principal						$ 981,245,000		$ 981,245,000		$ 1,000,000,000
6.000% senior unsecured notes due 2023 | Senior Notes
Debt Instrument [Line Items]
Interest rate					6.00%
Repayment of senior unsecured notes				$ 80,900,000
Loss on extinguishment of debt								$ 1,600,000
Proceeds from Issuance of Secured Debt					$ 316,500,000
5.875% Alkali senior secured notes due 2042 | Senior Notes
Debt Instrument [Line Items]
Interest rate	5.875%					587.50%		587.50%
Proceeds from issuance of debt	$ 408,000,000
Principal						$ 425,000,000		$ 425,000,000		$ 0
Debt Issuance Costs, Gross	17,000,000
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Five	$ 49,900,000
Restricted cash						$ 18,600,000		$ 18,600,000
5.625% senior unsecured notes due 2024 | Senior Notes
Debt Instrument [Line Items]
Interest rate						562.50%		562.50%		562.50%
Principal						$ 341,135,000		$ 341,135,000		$ 341,135,000
6.500% senior unsecured notes due 2025 | Senior Notes
Debt Instrument [Line Items]
Interest rate						650.00%		650.00%		650.00%
Principal						$ 534,834,000		$ 534,834,000		$ 534,834,000
6.250% senior unsecured notes due 2026 | Senior Notes
Debt Instrument [Line Items]
Interest rate						625.00%		625.00%		625.00%
Principal						$ 339,310,000		$ 339,310,000		$ 359,799,000
7.750% senior unsecured notes due 2028 | Senior Notes
Debt Instrument [Line Items]
Interest rate						775.00%		775.00%		775.00%
Principal						$ 679,360,000		$ 679,360,000		$ 720,975,000

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Partners' Capital, Mezzanine Capital and Distributions (Common Cash Distributions Paid) (Details) - Common Unitholders - USD ($) $ / shares in Units, $ in Thousands	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022	Feb. 14, 2022	Nov. 12, 2021	Aug. 13, 2021	May 14, 2021
Partners Capital And Distributions [Line Items]
Date Paid		Aug. 12, 2022	May 13, 2022	Feb. 14, 2022	Nov. 12, 2021	Aug. 13, 2021	May 14, 2021
Per Unit Amount (in dollars per unit)		$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15
Total Amount		$ 18,387	$ 18,387	$ 18,387	$ 18,387	$ 18,387	$ 18,387
Subsequent Event
Partners Capital And Distributions [Line Items]
Date Paid	Nov. 14, 2022	Aug. 12, 2022
Subsequent Event | Forecast
Partners Capital And Distributions [Line Items]
Date Paid	Nov. 14, 2022
Per Unit Amount (in dollars per unit)	$ 0.15
Total Amount	$ 18,387

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Partners' Capital, Mezzanine Capital and Distributions (Narrative) (Details)					1 Months Ended	3 Months Ended		9 Months Ended
	Nov. 17, 2021 USD ($)	Nov. 16, 2021	Apr. 14, 2020 USD ($) shares	Sep. 23, 2019 USD ($) $ / shares shares	Dec. 31, 2021 shares	Sep. 30, 2022 USD ($) shares	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) shares	Sep. 30, 2021 USD ($)	May 16, 2022 USD ($) shares
Temporary Equity [Line Items]
Common units outstanding (in units) | shares					122,579,218	122,579,218		122,579,218
Preferred units, accumulated distributions						$ 18,684,000	$ 18,684,000	$ 56,052,000	$ 56,052,000
Net Income (Loss) Attributable to Redeemable Noncontrolling Interest						$ 0	7,082,000	30,443,000	17,639,000
Redemption accretion								$ 1,908,000
Cameron Highway Oil Pipeline | Affiliated Entity
Temporary Equity [Line Items]
Sale of Stock, Consideration Received on Transaction	$ 418,000,000
Sale of Stock, Percentage of Ownership after Transaction					64.00%
Sale Of Stock, Percentage Of Ownership Sold		0.36						0.36
Independence Hub, LLC | Affiliated Entity | Genesis Energy, LLC
Temporary Equity [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent						80.00%		80.00%
Subsidiary | Alkali Holdings
Temporary Equity [Line Items]
Redeemable Noncontrolling Interest, Equity, Preferred, Purchase Price Per Unit | $ / shares				$ 1,000
Redeemable Noncontrolling Interest, Equity, Preferred, Units Issued, Value				$ 55,000,000				$ 18,500,000
Redeemable noncontrolling interest preferred commitment				$ 350,000,000
Expansion project extension period			1 year
Equity preferred units issued (in units) | shares			1,750
Commitment period			4 years
Net Income (Loss) Attributable to Redeemable Noncontrolling Interest							7,100,000	30,400,000	17,700,000
PIK distribution						$ 5,900,000		10,000,000	14,900,000
Redemption accretion							$ 1,200,000	$ 1,900,000	$ 2,800,000
Redemption value of redeemable preferred noncontrolling interest										$ 288,600,000
Period for occurrence of triggering events				6 years 6 months
Subsidiary | Minimum | Alkali Holdings
Temporary Equity [Line Items]
Redeemable noncontrolling interest preferred commitment				$ 251,800,000
Subsidiary | Maximum | Alkali Holdings
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares			351,750
Redeemable noncontrolling interest preferred commitment			$ 351,800,000
Common Class A | Limited Partner [Member]
Temporary Equity [Line Items]
Common units outstanding (in units) | shares						122,539,221		122,539,221
Common Class B | Limited Partner [Member]
Temporary Equity [Line Items]
Common units outstanding (in units) | shares						39,997		39,997
Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares					25,336,778	25,336,778		25,336,778
Preferred units, accumulated distributions						$ 18,700,000		$ 56,100,000
Redeemable Noncontrolling Interest Preferred Units
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares					246,394
Redeemable Noncontrolling Interest Preferred Units | Subsidiary | Alkali Holdings
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares				55,000		0		0		251,750

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Partners' Capital, Mezzanine Capital and Distributions (Preferred Cash Distributions Paid) (Details) - USD ($) $ / shares in Units, $ in Thousands	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022	Feb. 14, 2022	Nov. 12, 2021	Aug. 13, 2021	May 14, 2021
Preferred Unitholders | Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Date Paid			May 13, 2022	Feb. 14, 2022	Nov. 12, 2021	Aug. 13, 2021	May 14, 2021
Per Unit Amount (in dollars per unit)		$ 0.7374	$ 0.7374	$ 0.7374	$ 0.7374	$ 0.7374	$ 0.7374
Total Amount		$ 18,684	$ 18,684	$ 18,684	$ 18,684	$ 18,684	$ 18,684
Preferred Unitholders | Class A Convertible Preferred Stock Units | Forecast | Subsequent Event
Temporary Equity [Line Items]
Per Unit Amount (in dollars per unit)	$ 0.7374
Total Amount	$ 18,684
Common Unitholders
Temporary Equity [Line Items]
Date Paid		Aug. 12, 2022	May 13, 2022	Feb. 14, 2022	Nov. 12, 2021	Aug. 13, 2021	May 14, 2021
Per Unit Amount (in dollars per unit)		$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15
Total Amount		$ 18,387	$ 18,387	$ 18,387	$ 18,387	$ 18,387	$ 18,387
Common Unitholders | Subsequent Event
Temporary Equity [Line Items]
Date Paid	Nov. 14, 2022	Aug. 12, 2022
Common Unitholders | Forecast | Subsequent Event
Temporary Equity [Line Items]
Date Paid	Nov. 14, 2022
Per Unit Amount (in dollars per unit)	$ 0.15
Total Amount	$ 18,387

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Partners' Capital, Mezzanine Capital and Distributions (Changes in Redeemable Noncontrolling Interests) (Details) - USD ($)			3 Months Ended	9 Months Ended
	Apr. 14, 2020	Sep. 23, 2019	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Redeemable Noncontrolling Interest, Equity [Roll Forward]
Balance as of December 31, 2021				$ 259,568,000
Redeemable Noncontrolling Interest, Equity, Preferred, Units issued value, net of issuance costs				5,249,000
Redeemable Noncontrolling Interest, Equity, Preferred, Distributions Paid-in-Kind				9,993,000
Redemption accretion				1,908,000
Tax distributions				(6,631,000)
Balance as of May 16, 2022				0
Adjustment to Base Preferred Return Amount				18,542,000
Subsidiary | Alkali Holdings
Redeemable Noncontrolling Interest, Equity [Roll Forward]
Redemption accretion			$ 1,200,000	1,900,000	$ 2,800,000
Redeemable Noncontrolling Interest [Line Items]
Equity preferred units issued (in units)	1,750
Redeemable Noncontrolling Interest, Equity, Preferred, Units Issued, Value		$ 55,000,000		$ 18,500,000

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Net Loss Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings Per Share Reconciliation [Abstract]
Net income (loss) attributable to Genesis Energy, L.P.	$ 3,385	$ (20,899)	$ 33,482	$ (96,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)	(18,684)	(56,052)	(56,052)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(15,299)	(39,583)	(22,570)	(152,857)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (15,299)	$ (39,583)	$ (22,570)	$ (152,857)
Basic Weighted Average Outstanding Units (in units)	122,579,000	122,579,000	122,579,000	122,579,000
Dilutive Weighted Average Outstanding Units (in units)	122,579,000	122,579,000	122,579,000	122,579,000
Basic Net Loss per Common Unit (in dollars per unit)	$ (0.12)	$ (0.32)	$ (0.18)	$ (1.25)
Dilutive Net Loss per common unit (in dollars per unit)	$ (0.12)	$ (0.32)	$ (0.18)	$ (1.25)
Class A Convertible Preferred Stock Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities not included in computation of dilutive earnings (in units)			25,336,778

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Business Segment Information (Narrative) (Details)	9 Months Ended
	Sep. 30, 2022 segment
Segment Reporting [Abstract]
Number of reportable segments	4

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Business Segment Information (Schedule of Segment Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting Information [Line Items]
Segment margin	$ 196,190	$ 153,862	$ 572,914	$ 462,095
Total revenues	721,248	518,821	2,074,920	1,543,895
Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	89,805	69,479	239,958	207,084
Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total revenues	312,681	237,651	916,963	702,025
Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	240,967	162,975	708,110	498,113
Marine Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	77,795	48,716	209,889	136,673
Operating Segments
Segment Reporting Information [Line Items]
Segment margin	196,190	153,862	572,914	462,095
Capital expenditures	151,768	79,217	313,470	227,221
Total revenues	721,248	518,821	2,074,920	1,543,895
Operating Segments | Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	91,402	76,045	281,286	243,420
Capital expenditures	86,893	3,819	166,703	34,768
Total revenues	89,805	69,479	239,958	207,084
Operating Segments | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Segment margin	80,067	39,649	219,143	121,563
Capital expenditures	49,452	67,583	114,698	158,181
Total revenues	315,334	240,048	924,534	708,612
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	9,442	29,145	27,496	72,512
Capital expenditures	848	929	3,365	4,515
Total revenues	238,483	161,296	700,909	493,852
Operating Segments | Marine Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	15,279	9,023	44,989	24,600
Capital expenditures	14,575	6,886	28,704	29,757
Total revenues	77,626	47,998	209,519	134,347
Intersegment
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Intersegment | Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Intersegment | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total revenues	(2,653)	(2,397)	(7,571)	(6,587)
Intersegment | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	2,484	1,679	7,201	4,261
Intersegment | Marine Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	$ 169	$ 718	$ 370	$ 2,326

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Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Total consolidated assets	$ 6,169,539	$ 5,905,801
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total consolidated assets	2,214,924	2,103,140
Operating Segments | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	2,230,163	2,132,588
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	974,464	923,064
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total consolidated assets	692,303	703,030
Other assets
Segment Reporting Information [Line Items]
Total consolidated assets	$ 57,685	$ 43,979

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Business Segment Information (Reconciliation of Segment Margin to (Loss) Income from Continuing Operations) (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
	Apr. 29, 2022	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting [Abstract]
Net income (loss) attributable to Genesis Energy, L.P.		$ 3,385	$ (20,899)	$ 33,482	$ (96,805)
Corporate general and administrative expenses		18,132	14,878	54,958	38,389
Depreciation, depletion, amortization and accretion		(76,301)	(69,665)	225,526	208,346
Interest expense		57,710	59,940	168,773	176,938
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income		(5,247)	(7,142)	15,981	23,690
Other non-cash items		(24,636)	2,526	12,157	30,601
Distribution from unrestricted subsidiaries not included in income		0	17,500	(32,000)	(52,500)
Loss on extinguishment of debt		(293)	0	794	1,627
Differences in timing of cash receipts for certain contractual arrangements		13,775	657	38,482	7,402
Change in provision for leased items no longer in use		68	0	(599)	598
Redeemable noncontrolling interest redemption value adjustments		0	7,082	30,443	17,639
Income tax expense		660	423	1,535	1,170
Total Segment Margin		196,190	153,862	572,914	462,095
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives				(15,726)	(30,729)
Gain (Loss) on Disposition of Assets		0	0		0
Net income (loss) attributable to Genesis Energy, L.P.		3,385	(20,899)	33,482	(96,805)
Total Segment Margin		$ 196,190	153,862	572,914	462,095
Genesis NEJD Pipeline, LLC
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Cash receipts not included in income associated with principal payments of previously owned pipeline			$ 17,500	$ (32,000)	52,500
Genesis Energy, LLC | Affiliated Entity | Independence Hub, LLC
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		80.00%		80.00%
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Independence Hub, LLC
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Proceeds from Sale of Productive Assets	$ 40,000			$ 32,000
Embedded Derivative Financial Instruments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives		$ 25,000		$ 18,600	$ 31,000

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Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - Affiliated Entity - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
CEO
Related Party Transaction [Line Items]
Costs and expenses	$ 165	$ 165	$ 495	$ 495
Poseidon
Related Party Transaction [Line Items]
Revenues	3,854	3,193	10,952	10,221
Costs and expenses	$ 268	242	$ 777	720
Equity method investment, ownership percentage	64.00%		64.00%
ANSAC
Related Party Transaction [Line Items]
Revenues	$ 109,046	61,651	$ 294,556	200,935
Costs and expenses	$ 2,596	$ 400	$ 5,781	$ 1,097

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Transactions with Related Parties (Narrative) (Details) - Affiliated Entity - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Poseidon
Related Party Transaction [Line Items]
Related party transaction, revenues	$ 3,854	$ 3,193	$ 10,952	$ 10,221
Due from related parties	2,000		2,000		$ 2,400
Related party transaction, costs and expenses	268	242	777	720
Poseidon | Asset Management Arrangement
Related Party Transaction [Line Items]
Related party transaction, revenues	2,400	2,400	7,300	7,100
ANSAC
Related Party Transaction [Line Items]
Related party transaction, revenues	109,046	61,651	294,556	200,935
Due from related parties	103,582		103,582		$ 64,799
Related party transaction, costs and expenses	$ 2,596	$ 400	$ 5,781	$ 1,097

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Transactions with Related Parties (ANSAC) (Details) - ANSAC - Affiliated Entity - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Receivables	$ 103,582	$ 64,799
Payables	$ 2,596	$ 116

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Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
(Increase) decrease in:
Accounts receivable	$ (170,635)	$ 15,487
Inventories	(12,677)	11,108
Deferred charges	47,191	20,362
Other current assets	(4,717)	(10,335)
Increase (decrease) in:
Accounts payable	109,687	(50,361)
Accrued liabilities	(17,425)	20,196
Net changes in components of operating assets and liabilities	$ (48,576)	$ 6,457

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Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 189.2	$ 154.4
Interest paid, capitalized	11.2	2.3
Incurred liabilities for fixed and intangible asset additions	$ 67.6	$ 44.9

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Derivatives (Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments) (Details) bbl in Thousands, MMBTU in Thousands	9 Months Ended
	Sep. 30, 2022 MMBTU $ / bbl $ / MMBTU bbl
Designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	104
Weighted average contract price | $ / bbl	88.81
Designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	0
Weighted average contract price | $ / bbl	0
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	102
Weighted average contract price | $ / bbl	85.02
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	66
Weighted average contract price | $ / MMBTU	7.50
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	109
Weighted average contract price | $ / bbl	0.59
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Petroleum Products
Derivative [Line Items]
Contract volumes (bbls) | bbl	120
Weighted average contract price | $ / bbl	61.81
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Swaps | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	0
Weighted average contract price | $ / MMBTU	0
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	96
Weighted average contract price | $ / bbl	84.56
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	433
Weighted average contract price | $ / MMBTU	5.26
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	20
Weighted average contract price | $ / bbl	0.07
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Petroleum Products
Derivative [Line Items]
Contract volumes (bbls) | bbl	70
Weighted average contract price | $ / bbl	60.99
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swaps | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	367
Weighted average contract price | $ / MMBTU	(0.30)

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Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Not qualifying or not designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 3,688	$ 310
Derivative Asset, Fair Value, Gross Liability	(1,622)	(310)
Asset Derivatives	2,066	0
Derivative Liability, Fair Value, Gross Liability	(1,622)	(2,380)
Derivative Liability, Fair Value, Gross Asset	1,622	2,380
Liability Derivatives	0	0
Not qualifying or not designated as hedges under accounting rules | Swaps | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	221	1,867
Not qualifying or not designated as hedges under accounting rules | Swaps | Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(808)	(608)
Designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,599	49
Derivative Asset, Fair Value, Gross Liability	(557)	(49)
Asset Derivatives	1,042	0
Derivative Liability, Fair Value, Gross Liability	(557)	(209)
Derivative Liability, Fair Value, Gross Asset	557	209
Liability Derivatives	$ 0	$ 0

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Derivatives (Narrative) (Details)			6 Months Ended	9 Months Ended
	Sep. 29, 2022 USD ($)	Sep. 01, 2022	Jun. 30, 2022 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)
Derivatives, Fair Value [Line Items]
Net broker receivable				$ 5,800,000	$ 2,900,000
Initial margin				5,300,000	2,100,000
Variation margin			$ 800,000	500,000
Level 3 | Preferred Distribution Rate Reset Election
Derivatives, Fair Value [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs				$ 0	$ (83,210,000)
Embedded Derivative, Loss on Embedded Derivative	$ 101,800,000
Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Period to notify holders		30 days
Stock reset rate percentage	11.24%	10.75%			8.75%
Percentage below issue price per share		110.00%
Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Stock reset rate percentage	11.24%				8.75%
LIBOR | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price		0.0750
LIBOR | Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price	750
Stock reset rate percentage	3.74%

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Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Level 3 | Preferred Distribution Rate Reset Election
Derivative Instruments, Gain (Loss) [Line Items]
Net loss for the period included in earnings	$ (24,977)		$ (18,584)
Commodity derivatives - futures and call options | Cost of Goods and Services Sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	9,223	$ (456)	16,967	$ (13,616)
Natural Gas Swap | Cost of Goods and Services Sold | Sodium minerals and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(489)	(55)	(2,181)	(92)
Preferred Distribution Rate Reset Election | Other income (expense)
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income		1,740		(31,042)
Contracts designated as hedges under accounting guidance | Commodity derivatives - futures and call options | Cost of Goods and Services Sold | Onshore facilities and transportation product costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	2,085	(285)	1,549	(7,745)
Contracts not considered hedges under accounting guidance | Commodity derivatives - futures and call options | Cost of Goods and Services Sold | Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ 7,138	$ (171)	$ 15,418	$ (5,871)

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Fair-Value Measurements (Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels) (Details) - Recurring Fair Value Measures - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Level 1 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 5,287	$ 359
Liabilities Fair Value	(2,179)	(2,589)
Level 1 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 2 | Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	221	1,867
Liabilities Fair Value	(808)	(608)
Level 2 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 3 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	0	0
Level 3 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	$ 0	$ (83,210)

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Fair-Value Measurements (Reconciliation of Changes in Derivatives Classified as Level 3) (Details) - Level 3 - Preferred Distribution Rate Reset Election - USD ($) $ in Thousands		3 Months Ended	9 Months Ended
	Sep. 29, 2022	Sep. 30, 2022	Sep. 30, 2022
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance as of December 31, 2021			$ (83,210)
Net loss for the period included in earnings		$ (24,977)	(18,584)
Embedded Derivative, Loss on Embedded Derivative	$ 101,800
Balance as of September 30, 2022		$ 0	$ 0

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Fair-Value Measurements (Narrative) (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 29, 2022	Sep. 01, 2022	Dec. 31, 2021 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives		$ (15,726)	$ (30,729)
Carrying value of senior unsecured notes	$ 2,854,874	2,854,874				$ 2,930,505
Class A Convertible Preferred Stock Units
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Stock reset rate percentage				11.24%	10.75%	8.75%
Forecast | Class A Convertible Preferred Stock Units
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Stock reset rate percentage				11.24%		8.75%
Embedded Derivative Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives	25,000	18,600	$ 31,000
Carrying value of senior unsecured notes	2,900,000	2,900,000				$ 3,000,000
Fair value of senior unsecured notes	$ 2,600,000	$ 2,600,000				$ 3,000,000
Equity Volatility
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Embedded derivative liability, measurement input	0.50	0.50

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Subsequent Events (Details) - USD ($)		9 Months Ended
	Apr. 29, 2022	Sep. 30, 2022	Sep. 30, 2021
Subsequent Event [Line Items]
Payments to Noncontrolling Interests		$ 24,656,000	$ 0
Noncontrolling Interest [Member] | Independence Hub, LLC
Subsequent Event [Line Items]
Payments to Noncontrolling Interests	$ 8,000,000
Noncontrolling Interest [Member] | Independence Hub, LLC | Genesis Energy, LLC
Subsequent Event [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	20.00%
Independence Hub, LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Proceeds from Sale of Productive Assets	$ 40,000,000	$ 32,000,000
Subsequent Event | Noncontrolling Interest [Member] | Independence Hub, LLC
Subsequent Event [Line Items]
Payments to Noncontrolling Interests	$ 8,000,000
Subsequent Event | Noncontrolling Interest [Member] | Independence Hub, LLC | Genesis Energy, LLC
Subsequent Event [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	20.00%
Subsequent Event | Independence Hub, LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Proceeds from Sale of Productive Assets	$ 40,000,000