Genesis Energy (GEL) 10-Q 2 Nov 23 2023 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2023	Nov. 01, 2023
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
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	2023
Document Fiscal Period Focus	Q3
Amendment Flag	false
Class A Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		122,424,321
Class B Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		39,997

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
CURRENT ASSETS:
Cash and cash equivalents	$ 21,101	$ 7,930
Restricted cash	18,804	18,637
Accounts receivable - trade, net	871,298	721,567
Inventories	126,946	78,143
Other	53,396	26,770
Total current assets	1,091,545	853,047
FIXED ASSETS, at cost	6,248,511	5,865,038
Less: Accumulated depreciation	(1,925,879)	(1,768,465)
Net fixed assets	4,322,632	4,096,573
MINERAL LEASEHOLDS, net of accumulated depletion	541,866	545,122
EQUITY INVESTEES	270,294	284,486
INTANGIBLE ASSETS, net of amortization	141,703	127,320
GOODWILL	301,959	301,959
RIGHT OF USE ASSETS, net	229,785	125,277
OTHER ASSETS, net of amortization	38,658	32,208
TOTAL ASSETS	6,938,442	6,365,992
CURRENT LIABILITIES:
Accounts payable - trade	660,577	427,961
Accrued liabilities	363,136	281,146
Total current liabilities	1,023,713	709,107
SENIOR SECURED CREDIT FACILITY	198,400	205,400
SENIOR UNSECURED NOTES, net of debt issuance costs and premium	3,011,386	2,856,312
DEFERRED TAX LIABILITIES	17,577	16,652
OTHER LONG-TERM LIABILITIES	541,373	400,617
Total liabilities	5,186,769	4,590,530
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 23,853,538 and 25,336,778 issued and outstanding at September 30, 2023 and December 31, 2022, respectively	$ 839,695	$ 891,909
Common units outstanding (in units)	122,464,318	122,579,218
PARTNERS’ CAPITAL:
Common unitholders, 122,464,318 and 122,579,218 units issued and outstanding at September 30, 2023 and December 31, 2022, respectively	$ 547,622	$ 567,277
Accumulated other comprehensive income	6,479	6,114
Noncontrolling interests	357,877	310,162
Total partners’ capital	911,978	883,553
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ 6,938,442	$ 6,365,992
Common units issued (in units)	122,464,318	122,579,218
Class A Convertible Preferred Stock Units
PARTNERS’ CAPITAL:
Number preferred units issued (in units)	23,853,538	25,336,778
5.875% Alkali senior secured notes due 2042(2)
CURRENT LIABILITIES:
SENIOR SECURED CREDIT FACILITY	$ 394,320	$ 402,442

UNAUDITED CONDENSED CONSOLIDA_2

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2023	Dec. 31, 2022
Common units issued (in units)	122,464,318	122,579,218
Common units outstanding (in units)	122,464,318	122,579,218
Class A Convertible Preferred Stock Units
Number preferred units issued (in units)	23,853,538	25,336,778

UNAUDITED CONDENSED CONSOLIDA_3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
REVENUES:
Total revenues	$ 807,618	$ 721,248	$ 2,402,892	$ 2,074,920
COSTS AND EXPENSES:
General and administrative	16,770	17,038	48,253	52,825
Depreciation, depletion and amortization	68,379	73,946	209,966	217,125
Gain on sale of asset	0	0	0	(40,000)
Total costs and expenses	695,924	646,153	2,139,033	1,851,569
OPERATING INCOME	111,694	75,095	263,859	223,351
Equity in earnings of equity investees	17,242	13,236	49,606	40,252
Interest expense	(61,580)	(57,710)	(184,057)	(168,773)
Other expense	0	(21,388)	(1,812)	(10,758)
Income from operations before income taxes	67,356	9,233	127,596	84,072
Income tax expense	(574)	(660)	(1,748)	(1,535)
NET INCOME	66,782	8,573	125,848	82,537
Net income attributable to noncontrolling interests	(8,712)	(5,188)	(20,078)	(18,612)
Net income attributable to redeemable noncontrolling interests	0	0	0	(30,443)
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	58,070	3,385	105,770	33,482
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units	(22,308)	(18,684)	(69,220)	(56,052)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	35,762	(15,299)	36,550	(22,570)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ 35,762	$ (15,299)	$ 36,550	$ (22,570)
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax [Abstract]
Basic (in dollars per unit)	$ 0.29	$ (0.12)	$ 0.30	$ (0.18)
Diluted (in dollars per unit)	$ 0.29	$ (0.12)	$ 0.30	$ (0.18)
Earnings Per Unit [Abstract]
Basic (in units)	122,521	122,579	122,559	122,579
Diluted (in units)	122,521	122,579	122,559	122,579
Offshore pipeline transportation
REVENUES:
Total revenues	$ 106,297	$ 89,805	$ 289,151	$ 239,958
Offshore pipeline transportation | Offshore Pipeline Transportation Revenue
REVENUES:
Total revenues	106,297	89,805	289,151	239,958
COSTS AND EXPENSES:
Cost of products and services sold	23,651	25,410	71,515	74,785
Soda and sulfur services
REVENUES:
Total revenues	423,575	312,681	1,331,078	916,963
Soda and sulfur services | Sodium Minerals and Sulfur Services Revenue
REVENUES:
Total revenues	423,575	312,681	1,331,078	916,963
COSTS AND EXPENSES:
Cost of products and services sold	344,963	235,308	1,123,850	699,847
Marine transportation
REVENUES:
Total revenues	80,220	77,795	240,789	209,889
Marine transportation | Marine Transportation Revenue
REVENUES:
Total revenues	80,220	77,795	240,789	209,889
COSTS AND EXPENSES:
Cost of products and services sold	53,371	63,074	162,955	165,726
Onshore facilities and transportation
REVENUES:
Total revenues	197,526	240,967	541,874	708,110
Onshore facilities and transportation | Onshore Facilities and Transportation Revenue
REVENUES:
Total revenues	197,526	240,967	541,874	708,110
Onshore facilities and transportation | Onshore Facilities and Transportation Product
COSTS AND EXPENSES:
Cost of products and services sold	171,142	213,680	469,627	630,985
Onshore facilities and transportation | Onshore Facilities and Transportation Services
COSTS AND EXPENSES:
Cost of products and services sold	$ 17,648	$ 17,697	$ 52,867	$ 50,276

UNAUDITED CONDENSED CONSOLIDA_4

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Net loss	$ 66,782	$ 8,573	$ 125,848	$ 82,537
Other comprehensive income:
Decrease in benefit plan liability	122	122	365	365
Total Comprehensive income	66,904	8,695	126,213	82,902
Comprehensive income attributable to noncontrolling interests	(8,712)	(5,188)	(20,078)	(18,612)
Comprehensive income attributable to redeemable noncontrolling interests	0	0	0	(30,443)
Comprehensive income attributable to Genesis Energy, L.P.	$ 58,192	$ 3,507	$ 106,135	$ 33,847

UNAUDITED CONDENSED CONSOLIDA_5

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, 2021			122,579
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)
Cash distributions to noncontrolling interests	(24,656)			(24,656)
Cash contributions from noncontrolling interests	19,239			19,239
Other comprehensive income	365				365
Distributions and returns attributable to Class A Convertible Preferred unitholders	(56,052)	(56,052)
Adjustment to valuation of noncontrolling interest in subsidiary		(1,209)		1,209
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 and returns attributable 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)
Partners' capital, beginning balance (in shares) at Dec. 31, 2022			122,579
Partners' capital, beginning balance at Dec. 31, 2022	$ 883,553	567,277		310,162	6,114
Increase (Decrease) in Partners' Capital [Roll Forward]
Repurchase of Class A common units (in shares)	(115)
Repurchase of Class A common units	$ (1,044)
Net income	125,848	105,770		20,078
Cash distributions to partners	(55,161)	(55,161)
Cash distributions to noncontrolling interests	(33,203)			(33,203)
Cash contributions from noncontrolling interests	60,840			60,840
Other comprehensive income	365				365
Distributions and returns attributable to Class A Convertible Preferred unitholders	(69,220)	(69,220)
Partners' capital, ending balance (in shares) at Sep. 30, 2023			122,464
Partners' capital, ending balance at Sep. 30, 2023	911,978	547,622		357,877	6,479
Partners' capital, beginning balance (in shares) at Jun. 30, 2023			122,579
Partners' capital, beginning balance at Jun. 30, 2023	$ 871,873	531,291		334,225	6,357
Increase (Decrease) in Partners' Capital [Roll Forward]
Repurchase of Class A common units (in shares)	(115)
Repurchase of Class A common units	$ (1,044)
Net income	66,782	58,070		8,712
Cash distributions to partners	(18,387)	(18,387)
Cash distributions to noncontrolling interests	(10,980)			(10,980)
Cash contributions from noncontrolling interests	25,920			25,920
Other comprehensive income	122				122
Distributions and returns attributable to Class A Convertible Preferred unitholders	(22,308)	(22,308)
Partners' capital, ending balance (in shares) at Sep. 30, 2023			122,464
Partners' capital, ending balance at Sep. 30, 2023	$ 911,978	$ 547,622		$ 357,877	$ 6,479

UNAUDITED CONDENSED CONSOLIDA_6

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 125,848	$ 82,537
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation, depletion and amortization	209,966	217,125
Gain on sale of asset	0	(40,000)
Amortization and write-off of debt issuance costs, premium and discount	8,206	7,110
Equity in earnings of investments in equity investees	(49,606)	(40,252)
Cash distributions of earnings of equity investees	48,625	41,496
Non-cash effect of long-term incentive compensation plans	15,236	10,835
Deferred and other tax liabilities	925	1,010
Unrealized losses on derivative transactions	17,721	15,726
Cancellation of debt income	0	(8,619)
Other, net	15,839	14,203
Net changes in components of operating assets and liabilities (Note 15)	3,604	(48,576)
Net cash provided by operating activities	396,364	252,595
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(395,768)	(303,789)
Cash distributions received from equity investees - return of investment	19,600	14,737
Investments in equity investees	(4,463)	(5,441)
Proceeds from asset sales	307	40,281
Payments for (Proceeds from) Other Investing Activities	4,332
Net cash used in investing activities	(375,992)	(254,212)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	829,776	697,000
Repayments on senior secured credit facility	(836,776)	(625,800)
Net proceeds from issuance of Alkali senior secured notes (Note 10)	0	408,000
Redemption of redeemable noncontrolling interests (Note 11)	0	(288,629)
Proceeds from issuance of 2030 Notes (Note 10)	500,000	0
Repayment of senior unsecured notes (Note 10)	(341,135)	(72,241)
Debt issuance costs	(14,675)	(6,019)
Contributions from noncontrolling interests	60,840	19,239
Distributions to noncontrolling interests	(33,203)	(24,656)
Distributions to common unitholders	(55,161)	(55,161)
Distributions to Class A Convertible Preferred unitholders	(71,333)	(56,052)
Redemption of Class A Convertible Preferred Units (Note 11)	(50,000)	0
Repurchase of Class A common units (Note 11)	(1,044)	0
Other, net	5,677	5,429
Net cash provided by (used in) financing activities	(7,034)	1,110
Net increase (decrease) in cash, cash equivalents and restricted cash	13,338	(507)
Cash, cash equivalents and restricted cash at beginning of period	26,567	24,992
Cash, cash equivalents and restricted cash at end of period	$ 39,905	$ 24,485

Organization and Basis of Prese

Organization and Basis of Presentation and Consolidation	9 Months Ended
	Sep. 30, 2023
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 of Mexico, Wyoming and in the Gulf Coast region of the United States. We provide an integrated suite of services to refiners, crude oil and natural gas producers and industrial and commercial enterprises. We have a diverse portfolio of assets, including pipelines, offshore hub and junction platforms, our trona and trona-based exploring, mining, processing, producing, marketing, logistics and selling business based in Wyoming (our “Alkali Business”), refinery-related plants, storage tanks and terminals, railcars, 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 the transportation and processing of crude oil and natural gas in the Gulf of Mexico; • Soda and sulfur services involving trona and trona-based exploring, mining, processing, soda ash production, marketing, logistics and selling activities, as well as 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 includes terminaling, blending, storing, marketing, and transporting crude oil and petroleum 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. 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 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, 2022 (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 Accounting Developments

Recent Accounting Developments	9 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting DevelopmentsWe are currently evaluating new accounting pronouncements that have been issued, but are not yet effective. At this time, they are not expected to have a material impact on our financial positions or results of operations.

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2023
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, 2023 and 2022, respectively: Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 106,297 $ — $ 80,220 $ 16,769 $ 203,286 Product Sales — 399,329 — 180,757 580,086 Refinery Services — 24,246 — — 24,246 $ 106,297 $ 423,575 $ 80,220 $ 197,526 $ 807,618 Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities & 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 The following tables reflect the disaggregation of our revenues by major category for the nine months ended September 30, 2023 and 2022, respectively: Nine Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 289,151 $ — $ 240,789 $ 44,850 $ 574,790 Product Sales — 1,262,454 — 497,024 1,759,478 Refinery Services — 68,624 — — 68,624 $ 289,151 $ 1,331,078 $ 240,789 $ 541,874 $ 2,402,892 Nine Months Ended Offshore Pipeline Transportation Soda and 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 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. Contract Assets and Liabilities The table below depicts our contract asset and liability balances at December 31, 2022 and September 30, 2023: Contract Assets Contract Liabilities Other Assets, net of amortization Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2022 $ — $ 2,087 $ 64,478 Balance at September 30, 2023 181 5,127 95,213 Transaction Price Allocations to Remaining Performance Obligations We are required to disclose the aggregate amount of our transaction prices that are allocated to unsatisfied performance obligations as of September 30, 2023. However, we are permitted to utilize the following exemptions: 1) Performance obligations that are part of a contract with an expected duration of one year or less; 2) Revenue recognized from the satisfaction of performance obligations where we have a right to consideration in an amount that corresponds directly with the value provided to customers; and 3) Contracts that contain variable consideration, such as index-based pricing or variable volumes, that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that is part of a series. The majority of our contracts qualify for one of these exemptions. For the remaining contract types that involve revenue recognition over a long-term period and include 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 2023 $ 25,591 $ 1,800 2024 102,998 1,800 2025 116,730 — 2026 86,706 — 2027 50,006 — Thereafter 174,416 — Total $ 556,447 $ 3,600

Business Consolidation

Business Consolidation	3 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Business Consolidation	Business Consolidation American Natural Soda Ash Corporation (“ANSAC”) ANSAC is an organization whose purpose is to promote and market the use and sale of domestically produced natural soda ash in specified countries outside of the United States. Prior to 2023, our Alkali Business and another domestic soda ash producer were the two members of ANSAC. On January 1, 2023, we became the sole member of ANSAC and assumed 100% of the voting rights of the entity, and it became a wholly owned subsidiary of Genesis. We will continue to supply levels of our soda ash produced in the Green River Basin to ANSAC to utilize their logistical and marketing capabilities as an export vehicle for our Alkali Business. We determined that ANSAC meets the definition of a business and will account for our acquisition of ANSAC as a business combination. We have reflected the financial results of ANSAC within our soda and sulfur services segment from the date of acquisition, January 1, 2023. The purchase price has been allocated to the assets acquired and the liabilities assumed based on our estimated preliminary fair values. We expect to finalize the purchase price allocation by the end of 2023. There was no consideration transferred as a result of becoming the sole member of ANSAC. The preliminary allocation of the purchase price, as presented within our Unaudited Condensed Consolidated Balance Sheet as of September 30, 2023 is summarized as follows: Cash and cash equivalents $ 4,332 Accounts receivable - trade, net 231,797 Inventories 19,522 Other current assets 14,203 Fixed assets, at cost 4,000 Right of use assets, net 93,208 Intangible assets, net of amortization 14,992 Other Assets, net of amortization 400 Accounts payable - trade (1) (228,106) Accrued liabilities (75,224) Other long-term liabilities (79,124) Net Assets $ — (1) The “Accounts payable - trade” balance above includes $133.4 million of payables to Genesis at December 31, 2022 that eliminated upon consolidation in our Unaudited Condensed Consolidated Balance Sheet. Inventories principally relate to finished goods (soda ash) that have been supplied by current or former members of ANSAC. “Fixed assets, at cost” relate to leasehold improvements, and “Intangible assets, net of amortization” relate to our assets supporting our logistical and marketing footprint, and both have an estimated useful life of ten years, which is consistent with the term of our primary lease facilitating our logistics operations. Right of use assets, net and our corresponding lease liabilities, which are recorded within “Accrued liabilities” and “Other long-term liabilities,” respectively, are associated with our right to use certain assets to store and load finished goods, the vessels we utilize to ship finished goods to distributors and end users, as well as office space. Our Unaudited Condensed Consolidated Statement of Operations include the results of ANSAC since January 1, 2023. The following table presents selected financial information included in our Unaudited Consolidated Statement of Operations for the period presented: Three Months Ended Nine Months Ended Revenues $ 92,399 $ 321,853 Net Income Attributable to Genesis Energy, L.P. 5,373 10,644 The following unaudited pro forma financial information was prepared from our historical financial statements that have been adjusted to give the effect of the consolidation of ANSAC as though we had become the sole member on January 1, 2022. It is based upon assumptions deemed appropriate by us and may not be indicative of actual results. This pro forma information was prepared using financial data of ANSAC and reflects certain estimates and assumptions made by our management. Our unaudited pro forma financial information is not necessarily indicative of what our consolidated financial results would have been had we become the sole member on January 1, 2022. Pro forma net income (loss) attributable to common unitholders includes the effects of distributions attributable to our Class A Preferred Units. The dilutive effect of our preferred units is calculated using the if-converted method. Three Months Ended Nine Months Ended 2023 2022 2023 2022 Pro forma consolidated financial operating results: Revenues $ 807,618 $ 813,647 $ 2,402,892 $ 2,396,773 Net Income Attributable to Genesis Energy, L.P. 58,070 8,758 105,770 44,126 Net Income (Loss) Attributable to Common Unitholders 35,762 (9,926) 36,550 (11,926) Basic and diluted earnings (loss) per common unit: As reported net income (loss) per common unit $ 0.29 $ (0.12) $ 0.30 $ (0.18) Pro forma net income (loss) per common unit $ 0.29 $ (0.08) $ 0.30 $ (0.10)

Lease Accounting

Lease Accounting	9 Months Ended
	Sep. 30, 2023
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 (not greater than 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 12 months or fewer 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 as well as our unamortized prepaid rents, our deferred rents, and our previously classified intangible asset associated with a favorable lease. Current and non-current lease liabilities are recorded within “Accrued liabilities” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets. Lessor Arrangements We have certain contracts discussed below 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, 2023 and 2022, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, included in our marine transportation segment. Our lease revenues for this arrangement were $6.0 million and $17.7 million for the three and nine months ended September 30, 2023, respectively, and $1.8 million and $10.5 million for the three and nine months ended September 30, 2022, respectively. The M/T American Phoenix is under contract through mid-2027, and for the remainder of 2023, 2024, 2025, 2026, and through the expiration of the contract in 2027, we expect to receive undiscounted cash flows from lease payments of $6.0 million, $25.9 million, $29.6 million, $30.7 million, and $15.2 million, 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 (not greater than 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 12 months or fewer 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 as well as our unamortized prepaid rents, our deferred rents, and our previously classified intangible asset associated with a favorable lease. Current and non-current lease liabilities are recorded within “Accrued liabilities” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets. Lessor Arrangements We have certain contracts discussed below 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, 2023 and 2022, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, included in our marine transportation segment. Our lease revenues for this arrangement were $6.0 million and $17.7 million for the three and nine months ended September 30, 2023, respectively, and $1.8 million and $10.5 million for the three and nine months ended September 30, 2022, respectively. The M/T American Phoenix is under contract through mid-2027, and for the remainder of 2023, 2024, 2025, 2026, and through the expiration of the contract in 2027, we expect to receive undiscounted cash flows from lease payments of $6.0 million, $25.9 million, $29.6 million, $30.7 million, and $15.2 million, respectively.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Inventories	Inventories The major components of inventories were as follows: September 30, 2023 December 31, 2022 Petroleum products $ — $ 56 Crude oil 31,495 6,673 Caustic soda 9,184 15,258 NaHS 12,676 7,085 Raw materials - Alkali Business 7,601 5,819 Work-in-process - Alkali Business 7,691 9,599 Finished goods, net - Alkali Business 41,205 18,772 Materials and supplies, net - Alkali Business 17,094 14,881 Total $ 126,946 $ 78,143 Inventories are valued at the lower of cost or net realizable value. As of September 30, 2023 and December 31, 2022, the net realizable value of inventories were below cost by $0.1 million and $2.9 million, respectively, which triggered a reduction of the value of inventory in our Unaudited Condensed Consolidated Financial Statements by these amounts. 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.

Fixed Assets, Mineral Leasehold

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2023
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, 2023 December 31, 2022 Crude oil and natural gas pipelines and related assets $ 2,848,810 $ 2,844,288 Alkali facilities, machinery and equipment 787,040 701,313 Onshore facilities, machinery and equipment 270,676 269,949 Transportation equipment 25,652 22,340 Marine vessels 1,020,568 1,017,087 Land, buildings and improvements 238,697 231,651 Office equipment, furniture and fixtures 24,749 24,271 Construction in progress (1) 991,151 712,971 Other 41,168 41,168 Fixed assets, at cost 6,248,511 5,865,038 Less: Accumulated depreciation (1,925,879) (1,768,465) Net fixed assets $ 4,322,632 $ 4,096,573 (1) Construction in progress primarily relates to our Granger Optimization Project, which is expected to be completed in the fourth quarter of 2023, and our offshore growth capital projects, which are expected to be completed in 2024 and 2025. Mineral Leaseholds Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: September 30, 2023 December 31, 2022 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (24,153) (20,897) Mineral leaseholds, net of accumulated depletion $ 541,866 $ 545,122 Our depreciation and depletion expense for the periods presented were as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Depreciation expense $ 64,104 $ 70,328 $ 197,590 $ 206,111 Depletion expense 1,107 896 3,256 2,830 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, 2022: ARO liability balance, December 31, 2022 $ 228,573 Accretion expense 9,316 Changes in estimate 3,915 Settlements (68) ARO liability balance, September 30, 2023 $ 241,736 At September 30, 2023 and December 31, 2022, $26.1 million and $26.6 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, 2023 and December 31, 2022 is included in “Other long-term liabilities” on our Unaudited Condensed Consolidated Balance Sheets. Certain of our unconsolidated affiliates have AROs recorded at September 30, 2023 and December 31, 2022 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.

Equity Investees

Equity Investees	9 Months Ended
	Sep. 30, 2023
Equity Method Investments and Joint Ventures [Abstract]
Equity Investees	Equity Investees We account for our ownership in certain of 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, 2023 and December 31, 2022, the unamortized excess cost amounts totaled $294.9 million and $305.6 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 Nine Months Ended 2023 2022 2023 2022 Genesis’ share of operating earnings $ 20,908 $ 16,802 $ 60,304 $ 50,950 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,566) (10,698) (10,698) Net equity in earnings $ 17,242 $ 13,236 $ 49,606 $ 40,252 Distributions received (1) $ 23,629 $ 18,483 $ 68,141 $ 56,233 (1) Includes distributions attributable to the period and received during or within 15 days following the 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,” and its pipeline and associated assets, the “Poseidon pipeline”) (which we own 64% of and is our most significant equity investment): September 30, 2023 December 31, 2022 BALANCE SHEETS DATA: Assets Current assets $ 21,428 $ 27,878 Fixed assets, net 143,258 147,505 Other assets 16,629 13,419 Total assets $ 181,315 $ 188,802 Liabilities and equity Current liabilities $ 8,854 $ 10,087 Other liabilities 240,553 236,813 Equity (Deficit) (68,092) (58,098) Total liabilities and equity $ 181,315 $ 188,802 Three Months Ended Nine Months Ended 2023 2022 2023 2022 STATEMENTS OF OPERATIONS DATA: Revenues $ 43,316 $ 38,322 $ 123,462 $ 104,891 Operating income $ 33,213 $ 27,731 $ 94,216 $ 75,540 Net income $ 29,117 $ 25,502 $ 83,106 $ 70,850 Borrowings under Posei don’s revolving credit facility, which was amended and restated on June 1, 2023 (the “June 2023 credit facility”), are primarily used to fund spending on capital projects. The June 2023 credit facility, which matures on June 1, 2027, is non-recourse to Poseidon’s owners and secured by its assets. T

Intangible Assets

Intangible Assets	9 Months Ended
	Sep. 30, 2023
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, 2023 December 31, 2022 Gross Accumulated Carrying Gross Accumulated Carrying Offshore pipeline contract intangibles 158,101 67,956 90,145 158,101 61,715 96,386 Other 68,280 16,722 51,558 45,191 14,257 30,934 Total $ 226,381 $ 84,678 $ 141,703 $ 203,292 $ 75,972 $ 127,320 Our amortization of intangible assets for the periods presented was as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Amortization of intangible assets $ 3,069 $ 2,575 $ 8,747 $ 7,740 We estimate that our amortization expense for the next five years will be as follows: Remainder of 2023 $ 3,688 2024 14,556 2025 14,295 2026 13,983 2027 13,537

Debt

Debt	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Debt	Debt Our obligations under debt arrangements consisted of the following: September 30, 2023 December 31, 2022 Principal Unamortized Premium, Discount and Debt Issuance Costs Net Value Principal Unamortized Premium, Discount and Debt Issuance Costs Net Value Senior secured credit facility (1) $ 198,400 $ — $ 198,400 $ 205,400 $ — $ 205,400 5.625% senior unsecured notes due 2024 — — — 341,135 1,249 339,886 6.500% senior unsecured notes due 2025 534,834 2,374 532,460 534,834 3,265 531,569 6.250% senior unsecured notes due 2026 339,310 1,929 337,381 339,310 2,481 336,829 8.000% senior unsecured notes due 2027 981,245 3,891 977,354 981,245 4,956 976,289 7.750% senior unsecured notes due 2028 679,360 6,496 672,864 679,360 7,621 671,739 8.875% senior unsecured notes due 2030 500,000 8,673 491,327 — — — 5.875% Alkali senior secured notes due 2042 (2) 425,000 21,985 403,015 425,000 22,558 402,442 Total long-term debt $ 3,658,149 $ 45,348 $ 3,612,801 $ 3,506,284 $ 42,130 $ 3,464,154 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), were $6.3 million and $2.6 million as of September 30, 2023 and December 31, 2022, respectively. (2) As of September 30, 2023, $8.7 million of the principal balance is considered current and included within “Accrued liabilities” on the Unaudited Condensed Consolidated Balance Sheet. Senior Secured Credit Facility On February 17, 2023, we entered into the Sixth Amended and Restated Credit Agreement (our “new credit agreement”) to replace our Fifth Amended and Restated Credit Agreement. Our new credit agreement provides for a $850 million senior secured revolving credit facility. The new credit agreement matures on February 13, 2026, subject to extension at our request for one At September 30, 2023, the key terms for rates under our senior secured credit facility (which are dependent on our leverage ratio as defined in the new credit agreement) 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 new credit agreement) 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 new credit agreement) 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 3.50% on Term SOFR borrowings and from 1.25% to 2.50% 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, 2023, the applicable margins on our borrowings were 1.75% for alternate base rate borrowings and 2.75% for Term SOFR borrowings based on our leverage ratio. • Letter of credit fee rates range from 2.25% to 3.50% based on our leverage ratio as computed under the credit agreement and can fluctuate quarterly. At September 30, 2023, our letter of credit rate was 2.75%. • We pay a commitment fee on the unused portion of the senior secured revolving credit facility. 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, 2023, our commitment fee rate on the unused committed amount was 0.50%. • We have the ability to increase the aggregate size of the senior secured credit facility by an additional $200 million, subject to lender consent and certain other customary conditions. At September 30, 2023, we had $198.4 million borrowed under our new credit agreement, with $21.7 million of the borrowed amount designated as a loan under the inventory sublimit. Our credit agreement allows up to $100 million of the capacity to be used for letters of credit, of which $9.5 million was outstanding at September 30, 2023. Due to the revolving nature of loans under our senior secured credit facility, additional borrowings, periodic repayments and re-borrowings may be made until the maturity date. The total amount available for borrowings under our senior secured credit facility at September 30, 2023 was $642.1 million, subject to compliance with covenants. Our new 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. As of September 30, 2023, principal repayments totaling $65.3 million are due within the next five years, with the remaining quarterly principal repayments due thereafter through March 31, 2042. As of September 30, 2023, $8.7 million of the principal balance is considered current and included within “Accrued liabilities” on the Unaudited Condensed Consolidated Balance Sheet. 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, 2023, our liquidity reserve account had a balance of $18.8 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 11 ) and utilized the remainder to repay a portion of the outstanding borrowings under our senior secured credit facility as well as fund our liquidity reserve account. Senior Unsecured Note Transactions On January 25, 2023, we issued $500.0 million in aggregate principal amount of 8.875% senior unsecured notes due April 15, 2030 (the “2030 Notes”). Interest payments are due April 15 and October 15 of each year with the initial interest payment due on October 15, 2023. The net proceeds were used to purchase $316.3 million of our existing 2024 Notes, including the related accrued interest and tender premium and fees on those notes that were tendered in the tender offer that ended January 24, 2023. The remaining proceeds at that time were used to repay a portion of the borrowings outstanding under our senior secured credit facility and for general partnership purposes. On January 26, 2023, we issued a notice of redemption for the remaining principal of $24.8 million of our 2024 Notes and discharged the indebtedness with respect to the 2024 Notes on February 14, 2023. Our $3.0 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, LLC (“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.

Partners' Capital, Mezzanine Ca

Partners' Capital, Mezzanine Capital and Distributions	9 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Partners' Capital, Mezzanine Capital and Distributions	Partners’ Capital, Mezzanine Capital and Distributions At September 30, 2023, our outstanding common units consisted of 122,424,321 Class A Common Units and 39,997 Class B Common Units. The Class A Common Units are traditional common units in us. The Class B Common Units are identical to the Class A Common Units and, accordingly, have voting and distribution rights equivalent to those of the Class A Common Units, and, in addition, the Class B Common Units have the right to elect all of our board of directors and are convertible into Class A Common Units under certain circumstances, subject to certain exceptions. At September 30, 2023, we had 23,853,538 Class A Convertible Preferred Units outstanding, which are discussed below in further detail. In an effort to return capital to our investors, we announced a common equity repurchase program (the “Repurchase Program”) on August 8, 2023. The Repurchase Program authorizes the repurchase from time to time of up to 10% of our then outstanding Class A Common Units, or 12,253,922 units, via open market purchases or negotiated transactions conducted in accordance with applicable regulatory requirements. These repurchases may be made pursuant to a repurchase plan or plans that comply with Rule 10b5-1 under the Securities Exchange Act of 1934. The Repurchase Program will be reviewed no later than December 31, 2024 and may be suspended or discontinued at any time prior thereto. The Repurchase Program does not create an obligation for us to acquire a particular number of Class A Common Units and any Class A Common Units repurchased will be canceled. During the three months ended September 30, 2023, we repurchased and cancelled a total of 114,900 Class A Common Units at an average price of approximately $9.09 per unit for a total purchase price of $1.0 million, including commissions, which is reflected as a reduction to the carrying value of our “Partners’ Capital - Common unitholders” on our Unaudited Condensed Consolidated Balance Sheet. Distributions We paid or will pay the following cash distributions to our common unitholders in 2022 and 2023: Distribution For Date Paid Per Unit Total 2022 1 st Quarter May 13, 2022 $ 0.15 $ 18,387 2 nd Quarter August 12, 2022 $ 0.15 $ 18,387 3 rd Quarter November 14, 2022 $ 0.15 $ 18,387 4 th Quarter February 14, 2023 $ 0.15 $ 18,387 2023 1 st Quarter May 15, 2023 $ 0.15 $ 18,387 2 nd Quarter August 14, 2023 $ 0.15 $ 18,387 3 rd Quarter (1) November 14, 2023 $ 0.15 $ 18,370 (1) This distribution was declared in October 2023 and will be paid to unitholders of record as of October 31, 2023. 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 contained a distribution Rate Reset Election (as defined in Note 16 ), 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 feature was bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period. As of the Election Date, the feature within the Class A Convertible Preferred Units that required bifurcation no longer existed and we adjusted the carrying value of the Class A Convertible Preferred Units to include the fair value of the previously bifurcated embedded derivative at the Election Date. Refer to Note 16 for additional discussion. On April 3, 2023 and July 3, 2023, we entered into purchase agreements with the Class A Convertible Preferred unitholders whereby we redeemed a total of 1,483,240 Class A Convertible Preferred Units (the “Redeemed Units”) at an average purchase price of $33.71 per unit. The Redeemed Units had a carrying value of $35.20 per unit resulting in returns attributable to the Class A Convertible Preferred Units. Net Income Attributable to Genesis Energy, L.P. is adjusted for distributions and returns attributable to the Class A Convertible Preferred Units that accumulate in the period. Net Income Attributable to Genesis Energy, L.P. was reduced by $23.3 million and $71.3 million for the three and nine months ending September 30, 2023, respectively, and $18.7 million and $56.1 million, for the three and nine months ending September 30, 2022, respectively, due to Class A Convertible Preferred Unit distributions paid in the period (Class A Convertible Preferred Unit distributions are summarized in the table below). For the three and nine months ended September 30, 2023, Net Income Attributable to Genesis Energy L.P. was increased by $1.0 million and $2.1 million, respectively, due to returns attributable to the Class A Convertible Preferred Units accumulated in the period. As of September 30, 2023, 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 redemption first becomes probable and the date the units can first be redeemed. We paid, or will pay, by the dates noted below, the following cash distributions to our Class A Convertible Preferred unitholders in 2022 and 2023: Distribution For Date Paid Per Unit Total 2022 1 st Quarter May 13, 2022 $ 0.7374 $ 18,684 2 nd Quarter August 12, 2022 $ 0.7374 $ 18,684 3 rd Quarter November 14, 2022 $ 0.7374 $ 18,684 4 th Quarter February 14, 2023 $ 0.9473 $ 24,002 2023 1 st Quarter May 15, 2023 $ 0.9473 $ 24,002 2 nd Quarter (1) August 14, 2023 $ 0.9473 $ 23,314 3 rd Quarter (2) November 14, 2023 $ 0.9473 $ 22,612 (1) Approximately $0.7 million of this distribution was associated with the Redeemed Units and paid on July 3, 2023. (2) This distribution was declared in October 2023 and will be paid to unitholders of record as of October 31, 2023 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, logistics and selling business, including its Granger facility near Green River, Wyoming. Alkali Holdings utilized the net proceeds received from the issuance of 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 fourth quarter of 2023. In consideration of 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, 2023, 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, $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. Noncontrolling Interests We own a 64% membership interests in Cameron Highway Oil Pipeline Co. (“CHOPS”) and are the operator of its pipeline and associated assets (the “CHOPS pipeline”). We also own an 80% membership interest in Independence Hub, LLC. 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.

Net Loss Per Common Unit

Net Loss Per Common Unit	9 Months Ended
	Sep. 30, 2023
Net Income per Common Unit [Abstract]
Net Loss Per Common Unit	Net Income Per Common Unit Basic net income (loss) per common unit is computed by dividing net income 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 (loss) per common unit calculation for the period being presented. The numerator is adjusted for distributions declared in the period, undeclared distributions that accumulated during the period, and any returns that accumulated in the period. For the three and nine months ended September 30, 2023 and 2022, the effect of the assumed conversion of all the outstanding 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 attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net income (loss) per common unit (in thousands): Three Months Ended Nine Months Ended 2023 2022 2023 2022 Net income attributable to Genesis Energy, L.P. $ 58,070 $ 3,385 $ 105,770 $ 33,482 Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units (22,308) (18,684) (69,220) (56,052) Net income (loss) attributable to common unitholders $ 35,762 $ (15,299) $ 36,550 $ (22,570) Weighted average outstanding units 122,521 122,579 122,559 122,579 Basic and diluted net income (loss) per common unit $ 0.29 $ (0.12) $ 0.30 $ (0.18)

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2023
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, which includes the transportation and processing of crude oil and natural gas in the Gulf of Mexico; • Soda and sulfur services involving trona and trona-based exploring, mining, processing, soda ash production, marketing, logistics and selling activities, as well as 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 includes terminaling, blending, storing, marketing, and transporting crude oil and petroleum 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. 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.

Transactions with Related Parti

Transactions with Related Parties	9 Months Ended
	Sep. 30, 2023
Related Party Transactions [Abstract]
Transactions with Related Parties	Transactions with Related Parties Transactions with ANSAC prior to January 1, 2023 were considered transactions with a related party. As discussed in Note 4 , on January 1, 2023, ANSAC became a wholly owned subsidiary of Genesis. For comparability purposes, the transactions reflected in the table below for the three and nine months ended September 30, 2022 do not include the activity related to ANSAC. The transactions with related parties were as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Revenues: Revenues from services and fees to Poseidon (1) $ 4,812 $ 3,854 $ 13,858 $ 10,952 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 $ 495 $ 495 Charges for services and product purchases from Poseidon (1) 6,797 268 8,834 777 (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 reflect what we could have obtained 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, 2023 include $2.5 million and $7.5 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, 2022 include $2.4 million and $7.3 million, respectively, of fees we earned through the provision of services under that agreement. At September 30, 2023 and December 31, 2022, Poseidon owed us $2.2 million and $2.4 million, respectively, for services rendered.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2023
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 2023 2022 (Increase) decrease in: Accounts receivable $ 54,474 $ (170,635) Inventories (29,281) (12,677) Deferred charges 31,003 47,191 Other current assets (4,571) (4,717) Increase (decrease) in: Accounts payable (31,006) 109,687 Accrued liabilities (17,015) (17,425) Net changes in components of operating assets and liabilities $ 3,604 $ (48,576) Payments of interest and commitment fees were $196.3 million and $189.2 million for the nine months ended September 30, 2023 and September 30, 2022, respectively. We capitalized interest of $29.2 million and $11.2 million during the nine months ended September 30, 2023 and September 30, 2022, respectively.

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Crude Oil and Petroleum Products Hedges We have exposure to commodity price changes related to our petroleum inventory and purchase commitments. We utilize derivative instruments (exchange-traded futures, options and swap contracts) to hedge our exposure to crude oil, fuel oil and other 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. We recognize any changes in the fair value of our derivative contracts as increases or decreases in “Onshore facilities and transportation product costs” in the Unaudited Condensed Consolidated Statements of Operations. 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 product costs” in the Unaudited Condensed Consolidated Statements of Operations. Natural Gas Hedges 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 are used to 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 “Soda and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations. Forward Freight Hedges ANSAC is exposed to fluctuations in freight rates for vessels used to transport soda ash to our international customers. We use exchange-traded or over-the-counter futures, swaps and options to hedge future freight rates for forecasted shipments. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of forward freight contracts as increases or decreases within “Soda and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations. Bunker Fuel Hedges ANSAC is exposed to fluctuations in the price of bunker fuel consumed by vessels used to transport soda ash to our international customers. We use exchange-traded or over-the-counter futures, swaps and options to hedge bunker fuel prices for forecasted shipments. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of bunker fuel contracts as increases or decreases within “Soda and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations. Rail Fuel Surcharge Hedges ANSAC enters into rail transport agreements that require us to pay rail fuel surcharges based on changes in the U.S. On-Highway Diesel Fuel Price published by the U.S. Department of Energy (“DOE”). We use exchange-traded or over-the-counter futures, swaps and options to hedge fluctuations in the fuel price. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of bunker fuel contracts as increases or decreases within “Soda and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations. Balance Sheet Netting and Broker Margin Accounts 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 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. Our exchange-traded derivatives are transacted through brokerage accounts and are subject to margin requirements as established by the respective exchange. Margin requirements are intended to mitigate a party’s exposure to market volatility and counterparty credit risk. 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, 2023, we had a net broker receivable of approximately $14.5 million (consisting of initial margin of $7.2 million increased by $7.3 million variation margin). As of December 31, 2022, we had a net broker receivable of approximately $4.0 million (consisting of initial margin of $3.8 million increased by $0.2 million of variation margin). At September 30, 2023 and December 31, 2022, 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. Financial Statement Impacts Unrealized gains are subtracted from net income (loss) and unrealized losses are added to net income (loss) 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 (loss) 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. Outstanding Derivatives At September 30, 2023, we had the following outstanding derivative contracts that were entered into to economically hedge inventory, fixed price purchase commitments or forecasted purchases. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 398 192 Weighted average contract price per Bbl $ 80.23 $ 82.51 Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 59 33 Weighted average contract price per Bbl $ 84.75 $ 90.34 Natural gas swaps: Contract volumes (10,000 MMBtu) — 1,261 Weighted average price differential per MMBtu $ — $ 0.62 Natural gas futures: Contract volumes (10,000 MMBtu) 180 1,294 Weighted average contract price per MMBtu $ 2.71 $ 3.66 Natural gas options: Contract volumes (10,000 MMBtu) 59 32 Weighted average premium received/paid $ 0.66 $ 0.17 Bunker fuel futures: Contract volumes (metric tons “MT”) — 51,500 Weighted average price per MT $ — $ 535.99 DOE diesel options: Contract volumes (1,000 Gal) — 1,050 Weighted average premium received/paid $ — $ 0.27 Fair Value of Derivative Assets and Liabilities The following tables reflect the estimated fair value position of our derivatives at September 30, 2023 and December 31, 2022: Unaudited Condensed Consolidated Balance Sheets Location Fair Value September 30, 2023 December 31, 2022 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Accounts receivable - trade, net $ 10,082 $ 36,844 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other (1) 4,070 1,238 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (4,070) (1,238) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized assets Current Assets - Other (1) $ 1,304 $ — Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (1,304) — Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Liability Derivatives: Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued liabilities $ (2,695) $ (4,692) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (6,546) $ (11,061) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 6,546 5,217 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ (5,844) Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (3,885) $ — Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 3,885 — Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — (1) As noted above, our exchange-traded derivatives are transacted through brokerage accounts and subject to margin requirements. We offset fair value amounts recorded for our exchange-traded derivative contracts against required margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under “Current Assets - Other”. 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 11 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 Nine Months Ended 2023 2022 2023 2022 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (5,012) $ 2,085 $ (2,657) $ 1,549 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Soda and sulfur services operating costs (3,379) 7,138 (15,673) 15,418 Total commodity derivatives $ (8,391) $ 9,223 $ (18,330) $ 16,967 Natural Gas Swap Soda and sulfur services operating costs $ 8,600 $ (489) $ 15,086 $ (2,181) Preferred Distribution Rate Reset Election Other income (expense) $ — $ (24,977) $ — $ (18,584)

Fair-Value Measurements

Fair-Value Measurements	9 Months Ended
	Sep. 30, 2023
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, 2023 and December 31, 2022. September 30, 2023 December 31, 2022 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 5,374 $ 10,082 $ — $ 1,238 $ 36,844 $ — Liabilities $ (10,431) $ (2,695) $ — $ (11,061) $ (4,692) $ — Our commodity and fuel 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, 2023. See Note 16 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, 2023 our senior unsecured notes had a carrying value of approximately $3.0 billion and a fair value of approximately $2.9 billion compared to a carrying value of $2.9 billion and fair value of approximately $2.7 billion at December 31, 2022. 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. At September 30, 2023 and December 31, 2022, our Alkali senior secured notes had a carrying value and fair value of $0.4 billion. The fair value of the Alkali senior secured notes is determined based on trade information in the financial market of securities with similar features and is considered a Level 2 fair value measurement.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	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. 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.

Recent Accounting Developments

Recent Accounting Developments (Policies)	9 Months Ended
	Sep. 30, 2023
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. 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 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, 2022 (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.

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2023
Revenue Recognition [Abstract]
Schedule of Disaggregation of Revenue	The following tables reflect the disaggregation of our revenues by major category for the three months ended September 30, 2023 and 2022, respectively: Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 106,297 $ — $ 80,220 $ 16,769 $ 203,286 Product Sales — 399,329 — 180,757 580,086 Refinery Services — 24,246 — — 24,246 $ 106,297 $ 423,575 $ 80,220 $ 197,526 $ 807,618 Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities & 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
Schedule of Contract Asset and Liabilities Balances Activity		The table below depicts our contract asset and liability balances at December 31, 2022 and September 30, 2023: Contract Assets Contract Liabilities Other Assets, net of amortization Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2022 $ — $ 2,087 $ 64,478 Balance at September 30, 2023 181 5,127 95,213
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 2023 $ 25,591 $ 1,800 2024 102,998 1,800 2025 116,730 — 2026 86,706 — 2027 50,006 — Thereafter 174,416 — Total $ 556,447 $ 3,600

Business Consolidation (Tables)

Business Consolidation (Tables)	3 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Summary of Unaudited Consolidated Balance Sheet and Statements of Operations	The preliminary allocation of the purchase price, as presented within our Unaudited Condensed Consolidated Balance Sheet as of September 30, 2023 is summarized as follows: Cash and cash equivalents $ 4,332 Accounts receivable - trade, net 231,797 Inventories 19,522 Other current assets 14,203 Fixed assets, at cost 4,000 Right of use assets, net 93,208 Intangible assets, net of amortization 14,992 Other Assets, net of amortization 400 Accounts payable - trade (1) (228,106) Accrued liabilities (75,224) Other long-term liabilities (79,124) Net Assets $ — (1) The “Accounts payable - trade” balance above includes $133.4 million of payables to Genesis at December 31, 2022 that eliminated upon consolidation in our Unaudited Condensed Consolidated Balance Sheet. Three Months Ended Nine Months Ended Revenues $ 92,399 $ 321,853 Net Income Attributable to Genesis Energy, L.P. 5,373 10,644
Schedule of Pro Forma Financial Information	The dilutive effect of our preferred units is calculated using the if-converted method. Three Months Ended Nine Months Ended 2023 2022 2023 2022 Pro forma consolidated financial operating results: Revenues $ 807,618 $ 813,647 $ 2,402,892 $ 2,396,773 Net Income Attributable to Genesis Energy, L.P. 58,070 8,758 105,770 44,126 Net Income (Loss) Attributable to Common Unitholders 35,762 (9,926) 36,550 (11,926) Basic and diluted earnings (loss) per common unit: As reported net income (loss) per common unit $ 0.29 $ (0.12) $ 0.30 $ (0.18) Pro forma net income (loss) per common unit $ 0.29 $ (0.08) $ 0.30 $ (0.10)

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Schedule of Major Components of Inventories	The major components of inventories were as follows: September 30, 2023 December 31, 2022 Petroleum products $ — $ 56 Crude oil 31,495 6,673 Caustic soda 9,184 15,258 NaHS 12,676 7,085 Raw materials - Alkali Business 7,601 5,819 Work-in-process - Alkali Business 7,691 9,599 Finished goods, net - Alkali Business 41,205 18,772 Materials and supplies, net - Alkali Business 17,094 14,881 Total $ 126,946 $ 78,143

Fixed Assets, Mineral Leaseho_2

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2023
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule of Fixed Assets	Fixed assets consisted of the following: September 30, 2023 December 31, 2022 Crude oil and natural gas pipelines and related assets $ 2,848,810 $ 2,844,288 Alkali facilities, machinery and equipment 787,040 701,313 Onshore facilities, machinery and equipment 270,676 269,949 Transportation equipment 25,652 22,340 Marine vessels 1,020,568 1,017,087 Land, buildings and improvements 238,697 231,651 Office equipment, furniture and fixtures 24,749 24,271 Construction in progress (1) 991,151 712,971 Other 41,168 41,168 Fixed assets, at cost 6,248,511 5,865,038 Less: Accumulated depreciation (1,925,879) (1,768,465) Net fixed assets $ 4,322,632 $ 4,096,573
Schedule of Mineral Leaseholds	Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: September 30, 2023 December 31, 2022 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (24,153) (20,897) Mineral leaseholds, net of accumulated depletion $ 541,866 $ 545,122
Schedule of Depreciation and Depletion Expense	Our depreciation and depletion expense for the periods presented were as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Depreciation expense $ 64,104 $ 70,328 $ 197,590 $ 206,111 Depletion expense 1,107 896 3,256 2,830
Schedule of Change in Asset Retirement Obligation	The following table presents information regarding our AROs since December 31, 2022: ARO liability balance, December 31, 2022 $ 228,573 Accretion expense 9,316 Changes in estimate 3,915 Settlements (68) ARO liability balance, September 30, 2023 $ 241,736

Equity Investees (Tables)

Equity Investees (Tables)	9 Months Ended
	Sep. 30, 2023
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 Nine Months Ended 2023 2022 2023 2022 Genesis’ share of operating earnings $ 20,908 $ 16,802 $ 60,304 $ 50,950 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,566) (10,698) (10,698) Net equity in earnings $ 17,242 $ 13,236 $ 49,606 $ 40,252 Distributions received (1) $ 23,629 $ 18,483 $ 68,141 $ 56,233 (1) Includes distributions attributable to the period and received during or within 15 days following the 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,” and its pipeline and associated assets, the “Poseidon pipeline”) (which we own 64% of and is our most significant equity investment): September 30, 2023 December 31, 2022 BALANCE SHEETS DATA: Assets Current assets $ 21,428 $ 27,878 Fixed assets, net 143,258 147,505 Other assets 16,629 13,419 Total assets $ 181,315 $ 188,802 Liabilities and equity Current liabilities $ 8,854 $ 10,087 Other liabilities 240,553 236,813 Equity (Deficit) (68,092) (58,098) Total liabilities and equity $ 181,315 $ 188,802
Schedule Of Operations For Equity Investees	Three Months Ended Nine Months Ended 2023 2022 2023 2022 STATEMENTS OF OPERATIONS DATA: Revenues $ 43,316 $ 38,322 $ 123,462 $ 104,891 Operating income $ 33,213 $ 27,731 $ 94,216 $ 75,540 Net income $ 29,117 $ 25,502 $ 83,106 $ 70,850

Intangible Assets (Tables)

Intangible Assets (Tables)	9 Months Ended
	Sep. 30, 2023
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, 2023 December 31, 2022 Gross Accumulated Carrying Gross Accumulated Carrying Offshore pipeline contract intangibles 158,101 67,956 90,145 158,101 61,715 96,386 Other 68,280 16,722 51,558 45,191 14,257 30,934 Total $ 226,381 $ 84,678 $ 141,703 $ 203,292 $ 75,972 $ 127,320
Schedule of Amortization Expense	Our amortization of intangible assets for the periods presented was as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Amortization of intangible assets $ 3,069 $ 2,575 $ 8,747 $ 7,740
Schedule of Expected Amortization Expense	We estimate that our amortization expense for the next five years will be as follows: Remainder of 2023 $ 3,688 2024 14,556 2025 14,295 2026 13,983 2027 13,537

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Debt	Our obligations under debt arrangements consisted of the following: September 30, 2023 December 31, 2022 Principal Unamortized Premium, Discount and Debt Issuance Costs Net Value Principal Unamortized Premium, Discount and Debt Issuance Costs Net Value Senior secured credit facility (1) $ 198,400 $ — $ 198,400 $ 205,400 $ — $ 205,400 5.625% senior unsecured notes due 2024 — — — 341,135 1,249 339,886 6.500% senior unsecured notes due 2025 534,834 2,374 532,460 534,834 3,265 531,569 6.250% senior unsecured notes due 2026 339,310 1,929 337,381 339,310 2,481 336,829 8.000% senior unsecured notes due 2027 981,245 3,891 977,354 981,245 4,956 976,289 7.750% senior unsecured notes due 2028 679,360 6,496 672,864 679,360 7,621 671,739 8.875% senior unsecured notes due 2030 500,000 8,673 491,327 — — — 5.875% Alkali senior secured notes due 2042 (2) 425,000 21,985 403,015 425,000 22,558 402,442 Total long-term debt $ 3,658,149 $ 45,348 $ 3,612,801 $ 3,506,284 $ 42,130 $ 3,464,154 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), were $6.3 million and $2.6 million as of September 30, 2023 and December 31, 2022, respectively. (2) As of September 30, 2023, $8.7 million of the principal balance is considered current and included within “Accrued liabilities” on the Unaudited Condensed Consolidated Balance Sheet.

Partners' Capital, Mezzanine _2

Partners' Capital, Mezzanine Capital and Distributions (Tables)	9 Months Ended
	Sep. 30, 2023
Equity [Abstract]
Schedule of Paid Distributions	We paid or will pay the following cash distributions to our common unitholders in 2022 and 2023: Distribution For Date Paid Per Unit Total 2022 1 st Quarter May 13, 2022 $ 0.15 $ 18,387 2 nd Quarter August 12, 2022 $ 0.15 $ 18,387 3 rd Quarter November 14, 2022 $ 0.15 $ 18,387 4 th Quarter February 14, 2023 $ 0.15 $ 18,387 2023 1 st Quarter May 15, 2023 $ 0.15 $ 18,387 2 nd Quarter August 14, 2023 $ 0.15 $ 18,387 3 rd Quarter (1) November 14, 2023 $ 0.15 $ 18,370 (1) This distribution was declared in October 2023 and will be paid to unitholders of record as of October 31, 2023. We paid, or will pay, by the dates noted below, the following cash distributions to our Class A Convertible Preferred unitholders in 2022 and 2023: Distribution For Date Paid Per Unit Total 2022 1 st Quarter May 13, 2022 $ 0.7374 $ 18,684 2 nd Quarter August 12, 2022 $ 0.7374 $ 18,684 3 rd Quarter November 14, 2022 $ 0.7374 $ 18,684 4 th Quarter February 14, 2023 $ 0.9473 $ 24,002 2023 1 st Quarter May 15, 2023 $ 0.9473 $ 24,002 2 nd Quarter (1) August 14, 2023 $ 0.9473 $ 23,314 3 rd Quarter (2) November 14, 2023 $ 0.9473 $ 22,612 (1) Approximately $0.7 million of this distribution was associated with the Redeemed Units and paid on July 3, 2023. (2) This distribution was declared in October 2023 and will be paid to unitholders of record as of October 31, 2023

Net Loss Per Common Unit (Table

Net Loss Per Common Unit (Tables)	9 Months Ended
	Sep. 30, 2023
Net Income per Common Unit [Abstract]
Schedule of Computation of Earnings Per Share, Basic and Diluted	The following table reconciles net income attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net income (loss) per common unit (in thousands): Three Months Ended Nine Months Ended 2023 2022 2023 2022 Net income attributable to Genesis Energy, L.P. $ 58,070 $ 3,385 $ 105,770 $ 33,482 Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units (22,308) (18,684) (69,220) (56,052) Net income (loss) attributable to common unitholders $ 35,762 $ (15,299) $ 36,550 $ (22,570) Weighted average outstanding units 122,521 122,579 122,559 122,579 Basic and diluted net income (loss) per common unit $ 0.29 $ (0.12) $ 0.30 $ (0.18)

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Sep. 30, 2023
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Segment information for the periods presented below was as follows: Offshore Pipeline Transportation Soda and Sulfur Services Onshore Facilities and Transportation Marine Transportation Total Three Months Ended September 30, 2023 Segment Margin (1) $ 109,267 $ 61,957 $ 9,547 $ 27,126 $ 207,897 Capital expenditures (2) $ 149,489 $ 36,502 $ 6,696 $ 12,496 $ 205,183 Revenues: External customers $ 101,985 $ 425,913 $ 199,500 $ 80,220 $ 807,618 Intersegment (3) 4,312 (2,338) (1,974) — — Total revenues of reportable segments $ 106,297 $ 423,575 $ 197,526 $ 80,220 $ 807,618 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 Nine Months Ended September 30, 2023 Segment Margin (1) $ 300,505 $ 217,319 $ 21,242 $ 78,578 $ 617,644 Capital expenditures (2) $ 293,187 $ 83,109 $ 10,714 $ 32,543 $ 419,553 Revenues: External customers $ 284,839 $ 1,337,897 $ 539,367 $ 240,789 $ 2,402,892 Intersegment (3) 4,312 (6,819) 2,507 — — Total revenues of reportable segments $ 289,151 $ 1,331,078 $ 541,874 $ 240,789 $ 2,402,892 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 (1) A reconciliation of Net income 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, 2023 December 31, 2022 Offshore pipeline transportation $ 2,497,570 $ 2,290,488 Soda and sulfur services 2,573,777 2,358,086 Onshore facilities and transportation 1,146,639 981,354 Marine transportation 649,732 681,231 Other assets 70,724 54,833 Total consolidated assets $ 6,938,442 $ 6,365,992
Reconciliation of Segment Margin to (Loss) Income from Continuing Operations	Reconciliation of Net income attributable to Genesis Energy, L.P. to total Segment Margin: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Net income attributable to Genesis Energy, L.P. $ 58,070 $ 3,385 $ 105,770 $ 33,482 Corporate general and administrative expenses 18,329 18,132 52,580 54,958 Depreciation, depletion, amortization and accretion 71,099 76,301 218,788 225,526 Interest expense 61,580 57,710 184,057 168,773 Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) 6,387 5,247 18,535 15,981 Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value (2) (12,299) 26,295 17,721 16,083 Other non-cash items (7,228) (1,659) (16,886) (3,926) Distribution from unrestricted subsidiaries not included in income (3) — — — 32,000 Cancellation of debt income (4) — (3,881) — (8,618) Loss on extinguishment of debt — 293 1,812 794 Differences in timing of cash receipts for certain contractual arrangements (5) 11,385 13,775 33,519 38,482 Change in provision for leased items no longer in use — (68) — (599) Redeemable noncontrolling interest redemption value adjustments (6) — — — 30,443 Gain on sale of asset, net to our ownership interest (7) — — — (32,000) Income tax expense 574 660 1,748 1,535 Total Segment Margin $ 207,897 $ 196,190 $ 617,644 $ 572,914 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The three and nine months ended September 30, 2023 include unrealized gains of $12.3 million and unrealized losses of $17.7 million, respectively, from the valuation of our commodity derivative transactions (excluding fair value hedges). The three and nine months ended September 30, 2022 include unrealized losses of $1.3 million and unrealized gains of $2.5 million, respectively, from the valuation of our commodity derivative transactions (excluding fair value hedges), and 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. (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. (4) 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. (5) Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. (6) The nine months ended September 30, 2022 include PIK distributions, accretion on the redemption feature and valuation adjustments to the redemption feature as the associated preferred units were redeemed during the second quarter of 2022. Refer to Note 11 for details. (7) 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.

Transactions with Related Par_2

Transactions with Related Parties (Tables)	9 Months Ended
	Sep. 30, 2023
Related Party Transactions [Abstract]
Schedule Of Transactions with Related Parties	The transactions with related parties were as follows: Three Months Ended Nine Months Ended 2023 2022 2023 2022 Revenues: Revenues from services and fees to Poseidon (1) $ 4,812 $ 3,854 $ 13,858 $ 10,952 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 $ 495 $ 495 Charges for services and product purchases from Poseidon (1) 6,797 268 8,834 777

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 (Increase) decrease in: Accounts receivable $ 54,474 $ (170,635) Inventories (29,281) (12,677) Deferred charges 31,003 47,191 Other current assets (4,571) (4,717) Increase (decrease) in: Accounts payable (31,006) 109,687 Accrued liabilities (17,015) (17,425) Net changes in components of operating assets and liabilities $ 3,604 $ (48,576)

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments	At September 30, 2023, we had the following outstanding derivative contracts that were entered into to economically hedge inventory, fixed price purchase commitments or forecasted purchases. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 398 192 Weighted average contract price per Bbl $ 80.23 $ 82.51 Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 59 33 Weighted average contract price per Bbl $ 84.75 $ 90.34 Natural gas swaps: Contract volumes (10,000 MMBtu) — 1,261 Weighted average price differential per MMBtu $ — $ 0.62 Natural gas futures: Contract volumes (10,000 MMBtu) 180 1,294 Weighted average contract price per MMBtu $ 2.71 $ 3.66 Natural gas options: Contract volumes (10,000 MMBtu) 59 32 Weighted average premium received/paid $ 0.66 $ 0.17 Bunker fuel futures: Contract volumes (metric tons “MT”) — 51,500 Weighted average price per MT $ — $ 535.99 DOE diesel options: Contract volumes (1,000 Gal) — 1,050 Weighted average premium received/paid $ — $ 0.27
Schedule of Fair Value of Derivative Assets and Liabilities	The following tables reflect the estimated fair value position of our derivatives at September 30, 2023 and December 31, 2022: Unaudited Condensed Consolidated Balance Sheets Location Fair Value September 30, 2023 December 31, 2022 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Accounts receivable - trade, net $ 10,082 $ 36,844 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other (1) 4,070 1,238 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (4,070) (1,238) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized assets Current Assets - Other (1) $ 1,304 $ — Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (1,304) — Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Liability Derivatives: Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued liabilities $ (2,695) $ (4,692) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (6,546) $ (11,061) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 6,546 5,217 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ (5,844) Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (3,885) $ — Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 3,885 — Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ —
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 Nine Months Ended 2023 2022 2023 2022 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (5,012) $ 2,085 $ (2,657) $ 1,549 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Soda and sulfur services operating costs (3,379) 7,138 (15,673) 15,418 Total commodity derivatives $ (8,391) $ 9,223 $ (18,330) $ 16,967 Natural Gas Swap Soda and sulfur services operating costs $ 8,600 $ (489) $ 15,086 $ (2,181) Preferred Distribution Rate Reset Election Other income (expense) $ — $ (24,977) $ — $ (18,584)

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2023
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, 2023 and December 31, 2022. September 30, 2023 December 31, 2022 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 5,374 $ 10,082 $ — $ 1,238 $ 36,844 $ — Liabilities $ (10,431) $ (2,695) $ — $ (11,061) $ (4,692) $ —

Organization and Basis of Pre_2

Organization and Basis of Presentation and Consolidation (Details)	9 Months Ended
	Sep. 30, 2023 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregated Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Total revenues	$ 807,618	$ 721,248	$ 2,402,892	$ 2,074,920
Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	203,286	187,777	574,790	504,127
Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	580,086	511,410	1,759,478	1,491,165
Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	24,246	22,061	68,624	79,628
Offshore Pipeline Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	106,297	89,805	289,151	239,958
Offshore Pipeline Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	106,297	89,805	289,151	239,958
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	423,575	312,681	1,331,078	916,963
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	399,329	290,620	1,262,454	837,335
Sodium Minerals and Sulfur Services [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	24,246	22,061	68,624	79,628
Marine Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	80,220	77,795	240,789	209,889
Marine Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	80,220	77,795	240,789	209,889
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	197,526	240,967	541,874	708,110
Onshore Facilities and Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	16,769	20,177	44,850	54,280
Onshore Facilities and Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	180,757	220,790	497,024	653,830
Onshore Facilities and Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	$ 0	$ 0	$ 0	$ 0

Revenue Recognition (Contract A

Revenue Recognition (Contract Assets and Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Segment Reporting Information [Line Items]
Other Assets, net of amortization	$ 181	$ 0
Accrued Liabilities	5,127	2,087
Other Long-Term Liabilities	$ 95,213	$ 64,478

Revenue Recognition (Revenue Ex

Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in Thousands	Sep. 30, 2023 USD ($)
Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 556,447
Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	3,600
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 25,591
Revenue expected timing of satisfaction period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01 | 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, 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	$ 102,998
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, 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	$ 116,730
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, 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	$ 86,706
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, 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	$ 50,006
Revenue expected timing of satisfaction period	1 year
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, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 174,416
Revenue expected timing of satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0

Business Consolidation - Narrat

Business Consolidation - Narrative (Details)	Jan. 01, 2023
Leaseholds and Leasehold Improvements
Business Acquisition [Line Items]
Acquired fixed assets, useful life	10 years
American Natural Soda Ash Corp. (ANSAC)
Business Acquisition [Line Items]
Voting interests acquired	100%

Business Consolidation - Unaudi

Business Consolidation - Unaudited Consolidated Balance Sheet and Statements of Operations (Details) - American Natural Soda Ash Corp. (ANSAC) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2023	Jan. 01, 2023	Dec. 31, 2022
Business Acquisition [Line Items]
Cash and cash equivalents			$ 4,332
Accounts receivable - trade, net			231,797
Inventories			19,522
Other current assets			14,203
Fixed assets, at cost			4,000
Right of use assets, net			93,208
Intangible assets, net of amortization			14,992
Other Assets, net of amortization			400
Accounts payable - trade(1)			(228,106)
Accrued liabilities			(75,224)
Other long-term liabilities			(79,124)
Net Assets			$ 0
Revenues	$ 92,399	$ 321,853
Net Income Attributable to Genesis Energy, L.P.	$ 5,373	$ 10,644
Consolidation, Eliminations [Member]
Business Acquisition [Line Items]
Accounts receivable - trade, net				$ 133,400

Business Consolidations - Sched

Business Consolidations - Schedule of Pro Forma Financial Information (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pro forma consolidated financial operating results:
Revenues	$ 807,618	$ 813,647	$ 2,402,892	$ 2,396,773
Net Income Attributable to Genesis Energy, L.P.	58,070	8,758	105,770	44,126
Net Loss Attributable to Common Unitholders, Basic (in dollars per unit)	35,762	(9,926)	36,550	(11,926)
Net Loss Attributable to Common Unitholders, Diluted (in dollars per unit)	$ 35,762	$ (9,926)	$ 36,550	$ (11,926)
Basic and diluted earnings (loss) per common unit:
Basic Net Loss per Common Unit (in dollars per unit)	$ 0.29	$ (0.12)	$ 0.30	$ (0.18)
Dilutive Net Loss per common unit (in dollars per unit)	0.29	(0.12)	0.30	(0.18)
Pro Forma net loss per common unit, basic (in dollars per unit)	0.29	(0.08)	0.30	(0.10)
Pro forma net loss per common unit, diluted (in dollars per unit)	$ 0.29	$ (0.08)	$ 0.30	$ (0.10)

Lease Accounting (Details)

Lease Accounting (Details) - Marine Transportation [Member] - M/T American Phoenix [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Lessor, Lease, Description [Line Items]
Operating lease income	$ 6,000	$ 1,800	$ 17,700	$ 10,500
Lease payments, remainder of 2023	6,000		6,000
Lease payments, year one	25,900		25,900
Lease payments, year two	29,600		29,600
Lease payments, year three	30,700		30,700
Lease payments, year four	$ 15,200		$ 15,200

Inventories (Major Components o

Inventories (Major Components of Inventories) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Inventory Disclosure [Abstract]
Petroleum products	$ 0	$ 56
Crude oil	31,495	6,673
Caustic soda	9,184	15,258
NaHS	12,676	7,085
Raw materials - Alkali Business	7,601	5,819
Work-in-process - Alkali Business	7,691	9,599
Finished goods, net - Alkali Business	41,205	18,772
Materials and supplies, net - Alkali Business	17,094	14,881
Total	$ 126,946	$ 78,143

Inventories (Narrative) (Detail

Inventories (Narrative) (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Inventory Disclosure [Abstract]
Inventory write-down	$ 100	$ 2,900

Fixed Assets, Mineral Leaseho_3

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Fixed Assets, Net) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 6,248,511	$ 5,865,038
Less: Accumulated depreciation	(1,925,879)	(1,768,465)
Net fixed assets	4,322,632	4,096,573
Changes in estimate	3,915
Settlements	(68)
Asset retirement obligation balance	241,736	228,573
Accretion expense	9,316
Crude oil and natural gas pipelines and related assets
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	2,848,810	2,844,288
Onshore facilities, machinery and equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	270,676	269,949
Onshore facilities, machinery and equipment | Alkali Business
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	787,040	701,313
Transportation equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	25,652	22,340
Marine vessels
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	1,020,568	1,017,087
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	238,697	231,651
Office equipment, furniture and fixtures
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	24,749	24,271
Construction in progress(1)
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	991,151	712,971
Other
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 41,168	$ 41,168

Fixed Assets, Mineral Leaseho_4

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Mineral Leaseholds) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Fixed Assets And Asset Retirement Obligations [Abstract]
Mineral leaseholds	$ 566,019	$ 566,019
Less: Accumulated depletion	(24,153)	(20,897)
Mineral leaseholds, net of accumulated depletion	$ 541,866	$ 545,122

Fixed Assets, Mineral Leaseho_5

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 64,104	$ 70,328	$ 197,590	$ 206,111
Depletion expense	$ 1,107	$ 896	$ 3,256	$ 2,830

Fixed Assets, Mineral Leaseho_6

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Asset Retirement Obligation Rollforward) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2023 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2022	$ 228,573
Accretion expense	9,316
Changes in estimate	3,915
Settlements	(68)
ARO liability balance, September 30, 2023	$ 241,736

Fixed Assets, Mineral Leaseho_7

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 241,736	$ 228,573
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 26,100	$ 26,600

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 294.9	$ 305.6

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Equity Method Investments and Joint Ventures [Abstract]
Amortization of differences attributable to Genesis’ carrying value of equity investments	$ (3,566)	$ (3,566)	$ (10,698)	$ (10,698)
Distributions received	23,629	18,483	68,141	56,233
Equity in earnings of equity investees	17,242	13,236	49,606	40,252
Genesis’ share of operating earnings	$ 20,908	$ 16,802	$ 60,304	$ 50,950

Equity Investees (Schedule of B

Equity Investees (Schedule of Balance Sheet Information for Equity Investees) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Assets
Current assets	$ 1,091,545	$ 853,047
Fixed assets, net	4,322,632	4,096,573
Total assets	6,938,442	6,365,992
LIABILITIES AND CAPITAL
Current liabilities	1,023,713	709,107
Total liabilities and equity	6,938,442	6,365,992
Poseidon
Assets
Current assets	21,428	27,878
Fixed assets, net	143,258	147,505
Other assets	16,629	13,419
Total assets	181,315	188,802
LIABILITIES AND CAPITAL
Current liabilities	8,854	10,087
Other liabilities	240,553	236,813
Equity (Deficit)	(68,092)	(58,098)
Total liabilities and equity	$ 181,315	$ 188,802

Equity Investees (Schedule of O

Equity Investees (Schedule of Operations for Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
INCOME STATEMENT DATA:
Revenues	$ 807,618	$ 721,248	$ 2,402,892	$ 2,074,920
Operating income	111,694	75,095	263,859	223,351
Net income	58,070	3,385	105,770	33,482
Poseidon
INCOME STATEMENT DATA:
Revenues	43,316	38,322	123,462	104,891
Operating income	33,213	27,731	94,216	75,540
Net income	$ 29,117	$ 25,502	$ 83,106	$ 70,850

Intangible Assets (Schedule of

Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 226,381	$ 203,292
Accumulated Amortization	84,678	75,972
Carrying Value	141,703	127,320
Contract intangibles | Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	158,101	158,101
Accumulated Amortization	67,956	61,715
Carrying Value	90,145	96,386
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	68,280	45,191
Accumulated Amortization	16,722	14,257
Carrying Value	$ 51,558	$ 30,934

Intangible Assets - Schedule of

Intangible Assets - Schedule of Amortization Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization of intangible assets	$ 3,069	$ 2,575	$ 8,747	$ 7,740

Intangible Assets (Schedule o_2

Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Remainder of 2021	$ 3,688		$ 3,688
2024	14,556		14,556
2025	14,295		14,295
2026	13,983		13,983
2027	13,537		13,537
Amortization of intangible assets	$ 3,069	$ 2,575	$ 8,747	$ 7,740

Debt (Schedule of Obligations U

Debt (Schedule of Obligations Under Debt Arrangements) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Jan. 25, 2023	Dec. 31, 2022	May 17, 2022
Debt Instrument [Line Items]
Principal	$ 3,658,149		$ 3,506,284
Unamortized Premium, Discount and Debt Issuance Costs	45,348		42,130
Net Value	3,612,801		3,464,154
5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Principal	0		341,135
Unamortized Premium, Discount and Debt Issuance Costs	0		1,249
Net Value			339,886
5.875% Alkali senior secured notes due 2042(2)
Debt Instrument [Line Items]
Principal	400,000
Term Loan
Debt Instrument [Line Items]
Net Value	0
Credit Facility | Revolving Credit Facility | Revolving Loan
Debt Instrument [Line Items]
Principal	198,400		205,400
Unamortized Premium, Discount and Debt Issuance Costs	0		0
Net Value	198,400		205,400
Unamortized debt issuance costs	$ 6,300		2,600
Senior Notes | 5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Interest rate	5.625%
Senior Notes | 6.500% senior unsecured notes due 2025
Debt Instrument [Line Items]
Principal	$ 534,834		534,834
Unamortized Premium, Discount and Debt Issuance Costs	2,374		3,265
Net Value	$ 532,460		531,569
Interest rate	6.50%
Senior Notes | 6.250% senior unsecured notes due 2026
Debt Instrument [Line Items]
Principal	$ 339,310		339,310
Unamortized Premium, Discount and Debt Issuance Costs	1,929		2,481
Net Value	$ 337,381		336,829
Interest rate	6.25%
Senior Notes | 8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Principal	$ 981,245		981,245
Unamortized Premium, Discount and Debt Issuance Costs	3,891		4,956
Net Value	$ 977,354		976,289
Interest rate	8%
Senior Notes | 7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Principal	$ 679,360		679,360
Unamortized Premium, Discount and Debt Issuance Costs	6,496		7,621
Net Value	$ 672,864		671,739
Interest rate	7.75%
Senior Notes | 5.875% Alkali senior secured notes due 2042(2)
Debt Instrument [Line Items]
Principal	$ 425,000		425,000
Unamortized Premium, Discount and Debt Issuance Costs	21,985		22,558
Net Value	$ 403,015		402,442
Interest rate	5.875%			5.875%
2030 Notes | Senior Notes
Debt Instrument [Line Items]
Principal	$ 500,000		0
Unamortized Premium, Discount and Debt Issuance Costs	8,673		0
Net Value	$ 491,327		$ 0
Interest rate	8.875%	8.875%

Debt (Narrative) (Details)

Debt (Narrative) (Details)				1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Feb. 17, 2023 USD ($) extension	May 17, 2022 USD ($)	Dec. 31, 2021	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Jan. 25, 2023 USD ($)	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Repayment of senior unsecured notes							$ 341,135,000	$ 72,241,000
Loss on extinguishment of debt					$ 0	$ (293,000)	1,812,000	$ 794,000
Principal	$ 3,658,149,000				3,658,149,000		3,658,149,000			$ 3,506,284,000
Restricted cash	$ 18,804,000				$ 18,804,000		$ 18,804,000			18,637,000
Cameron Highway Oil Pipeline | Affiliated Entity
Debt Instrument [Line Items]
Percentage of ownership after transaction				64%
Senior Notes | Guarantor Subsidiary | Genesis Energy, LLC | Genesis Finance Corporation
Debt Instrument [Line Items]
Percentage of equity interest							100%
Senior Notes | 2030 Notes
Debt Instrument [Line Items]
Outstanding extension threshold		$ 150,000,000
Debt Instrument, Face Amount									$ 500,000,000
Interest rate	8.875%				8.875%		8.875%		8.875%
Principal	$ 500,000,000				$ 500,000,000		$ 500,000,000			0
Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Credit facility extension period		1 year
Credit facility, number of extensions | extension		2
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage	2.75%
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Letter of credit, fee percentage							3.50%
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]
Maximum borrowing capacity		$ 850,000,000
Line of credit, unused capacity commitment fee percentage	0.50%
Credit facility, additional borrowing capacity	$ 200,000,000				200,000,000		$ 200,000,000
Credit facility, amount borrowed	198,400,000				198,400,000		198,400,000
Letters of credit, outstanding amount	9,500,000				9,500,000		9,500,000
Line of Credit Facility, Remaining Borrowing Capacity	642,100,000				642,100,000		642,100,000
Principal	198,400,000				198,400,000		198,400,000			205,400,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount borrowed	21,700,000				21,700,000		$ 21,700,000
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		$ 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	175%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate							2.50%
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	275%
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							3.50%
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%
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%
5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Principal	$ 0				$ 0		$ 0			341,135,000
5.625% senior unsecured notes due 2024 | Senior Notes
Debt Instrument [Line Items]
Interest rate	5.625%				5.625%		5.625%
8.000% senior unsecured notes due 2027 | Senior Notes
Debt Instrument [Line Items]
Interest rate	8%				8%		8%
Principal	$ 981,245,000				$ 981,245,000		$ 981,245,000			981,245,000
5.875% Alkali senior secured notes due 2042(2)
Debt Instrument [Line Items]
Principal	$ 400,000,000				$ 400,000,000		$ 400,000,000
5.875% Alkali senior secured notes due 2042(2) | Senior Notes
Debt Instrument [Line Items]
Interest rate	5.875%		5.875%		5.875%		5.875%
Accrued Liabilities	$ 8,700,000				$ 8,700,000		$ 8,700,000
Proceeds from issuance of debt			$ 408,000,000
Principal	425,000,000				425,000,000		425,000,000			425,000,000
Debt Issuance Costs, Gross			$ 17,000,000
Long-term Debt, Maturities, Repayments of Principal in Rolling Year Five	65,300,000				65,300,000		65,300,000
Restricted cash	$ 18,800,000				$ 18,800,000		$ 18,800,000
6.500% senior unsecured notes due 2025 | Senior Notes
Debt Instrument [Line Items]
Interest rate	6.50%				6.50%		6.50%
Principal	$ 534,834,000				$ 534,834,000		$ 534,834,000			534,834,000
6.250% senior unsecured notes due 2026 | Senior Notes
Debt Instrument [Line Items]
Interest rate	6.25%				6.25%		6.25%
Principal	$ 339,310,000				$ 339,310,000		$ 339,310,000			339,310,000
7.750% senior unsecured notes due 2028 | Senior Notes
Debt Instrument [Line Items]
Interest rate	7.75%				7.75%		7.75%
Principal	$ 679,360,000				$ 679,360,000		$ 679,360,000			$ 679,360,000

Partners' Capital, Mezzanine _3

Partners' Capital, Mezzanine Capital and Distributions (Common Cash Distributions Paid) (Details) - Common Unitholders - USD ($) $ / shares in Units, $ in Thousands	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023	Feb. 14, 2023	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022
Partners Capital And Distributions [Line Items]
Date Paid		Aug. 14, 2023	May 15, 2023	Feb. 14, 2023	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022
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, 2023
Per Unit Amount (in dollars per unit)	$ 0.15
Total Amount	$ 18,370

Partners' Capital, Mezzanine _4

Partners' Capital, Mezzanine Capital and Distributions (Narrative) (Details)					1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 03, 2023 $ / shares shares	Apr. 03, 2023 $ / shares shares	Apr. 14, 2020 USD ($) shares	Sep. 23, 2019 USD ($) $ / shares shares	Dec. 31, 2021	Sep. 30, 2023 USD ($) $ / shares shares	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) shares	Sep. 30, 2022 USD ($)	Aug. 08, 2023 shares	Dec. 31, 2022 shares	Sep. 29, 2022	Sep. 01, 2022	May 16, 2022 USD ($) shares
Partners Capital And Distributions [Line Items]
Common units outstanding (in units) | shares						122,464,318		122,464,318			122,579,218
Stock repurchased and cancelled (in shares) | shares						115,000		115,000
Purchase price						$ 1,044,000		$ 1,044,000
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units						(22,308,000)	$ (18,684,000)	(69,220,000)	$ (56,052,000)
Redeemable noncontrolling interests, no units issued and outstanding at September 30, 2023 and 0 preferred units issued and outstanding June 30, 2023														$ 270,100,000
Net income attributable to redeemable noncontrolling interests						$ 0	0	$ 0	30,443,000
Cameron Highway Oil Pipeline | Affiliated Entity
Partners Capital And Distributions [Line Items]
Percentage of ownership after transaction					64%
Independence Hub, LLC | Affiliated Entity | Genesis Energy, LLC
Partners Capital And Distributions [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent						80%		80%
Subsidiary | Alkali Holdings
Partners Capital And Distributions [Line Items]
Period for occurrence of triggering events				6 years 6 months
Redeemable Noncontrolling Interest, Equity, Preferred, Units Issued, Value				$ 55,000,000					10,000,000
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
Redeemable Noncontrolling Interest, Equity, Preferred, Purchase Price Per Unit | $ / shares				$ 1,000
Redemption value of redeemable preferred noncontrolling interest														$ 288,600,000
Net income attributable to redeemable noncontrolling interests						$ 0	0	$ 0	30,443,000
Redemption accretion value adjustments									1,900,000
Subsidiary | Alkali Holdings | Maximum
Partners Capital And Distributions [Line Items]
Number of preferred units outstanding (in units) | shares			351,750
Redeemable noncontrolling interest preferred commitment			$ 351,800,000
Subsidiary | Alkali Holdings | Minimum
Partners Capital And Distributions [Line Items]
Redeemable noncontrolling interest preferred commitment				$ 251,800,000
Class A Common Units | 2023 Repurchase Program
Partners Capital And Distributions [Line Items]
Percentage of shares authorized for repurchase										0.10
Shares authorized to be repurchased (in shares) | shares										12,253,922
Stock repurchased and cancelled (in shares) | shares						114,900
Shares purchased (in shares) | $ / shares						$ 9.09
Purchase price						$ 1,000,000
Class A Convertible Preferred Stock Units
Partners Capital And Distributions [Line Items]
Class A Convertible Preferred Units redeemed (in shares) | shares	1,483,240	1,483,240
Class A Convertible Preferred units redeemed (in dollars per share) | $ / shares	$ 33.71	$ 33.71
Class A Convertible Preferred Units, carrying value (dollars per share) | $ / shares	$ 35.2	$ 35.2
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units						(23,300,000)	$ (18,700,000)	(71,300,000)	$ (56,100,000)
Temporary equity, adjustment						1,000,000		2,100,000
Stock reset rate percentage											8.75%	11.24%	10.75%
Redeemable Noncontrolling Interest Preferred Units
Partners Capital And Distributions [Line Items]
Base Preferred Return Amount, Alkali Holdings						$ 18,500,000		$ 18,500,000
Redeemable Noncontrolling Interest Preferred Units | Subsidiary | Alkali Holdings
Partners Capital And Distributions [Line Items]
Number of preferred units outstanding (in units) | shares				55,000		0		0						251,750
Limited Partner [Member] | Class A Common Units
Partners Capital And Distributions [Line Items]
Common units outstanding (in units) | shares						122,424,321		122,424,321
Limited Partner [Member] | Class B Common Units
Partners Capital And Distributions [Line Items]
Common units outstanding (in units) | shares						39,997		39,997
Limited Partner [Member] | Preferred Class A
Partners Capital And Distributions [Line Items]
Common units outstanding (in units) | shares						23,853,538		23,853,538

Partners' Capital, Mezzanine _5

Partners' Capital, Mezzanine Capital and Distributions (Preferred Cash Distributions Paid) (Details) - USD ($)	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023	Feb. 14, 2023	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022
Preferred Unitholders | Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Per Unit Amount (in dollars per unit)		$ 0.9473	$ 0.9473	$ 0.9473	$ 0.7374	$ 0.7374	$ 0.7374
Total Amount		$ 23,314,000	$ 24,002,000	$ 24,002,000	$ 18,684,000	$ 18,684,000	$ 18,684,000
Preferred Unitholders | Class A Convertible Preferred Stock Units | Subsequent Event
Temporary Equity [Line Items]
Total Amount	$ 22,612,000
Common Unitholders
Temporary Equity [Line Items]
Date Paid		Aug. 14, 2023	May 15, 2023	Feb. 14, 2023	Nov. 14, 2022	Aug. 12, 2022	May 13, 2022
Per Unit Amount (in dollars per unit)		$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15
Total Amount		$ 18,387,000	$ 18,387,000	$ 18,387,000	$ 18,387,000	$ 18,387,000	$ 18,387,000
Common Unitholders | Subsequent Event
Temporary Equity [Line Items]
Date Paid	Nov. 14, 2023
Per Unit Amount (in dollars per unit)	$ 0.15
Total Amount	$ 18,370,000

Partners' Capital, Mezzanine _6

Partners' Capital, Mezzanine Capital and Distributions (Changes in Redeemable Noncontrolling Interests) (Details) - USD ($)		3 Months Ended		9 Months Ended
	Sep. 23, 2019	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	May 16, 2022
Redeemable Noncontrolling Interest [Line Items]
Redeemable noncontrolling interests, no units issued and outstanding at September 30, 2023 and 0 preferred units issued and outstanding June 30, 2023						$ 270,100,000
Net income attributable to redeemable noncontrolling interests		$ 0	$ 0	$ 0	$ 30,443,000
Subsidiary | Alkali Holdings
Redeemable Noncontrolling Interest [Line Items]
Redemption value of redeemable preferred noncontrolling interest						$ 288,600,000
Net income attributable to redeemable noncontrolling interests		$ 0	$ 0	$ 0	30,443,000
Redeemable Noncontrolling Interest, Equity, Preferred, Units Issued, Value	$ 55,000,000				$ 10,000,000

Net Loss Per Common Unit (Detai

Net Loss Per Common Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net Income per Common Unit [Abstract]
Net income attributable to Genesis Energy, L.P.	$ 58,070	$ 3,385	$ 105,770	$ 33,482
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units	(22,308)	(18,684)	(69,220)	(56,052)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	35,762	(15,299)	36,550	(22,570)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ 35,762	$ (15,299)	$ 36,550	$ (22,570)
Dilutive Weighted Average Outstanding Units (in units)	122,521	122,579	122,559	122,579
Basic Net Loss per Common Unit (in dollars per unit)	$ 0.29	$ (0.12)	$ 0.30	$ (0.18)
Dilutive Net Loss per common unit (in dollars per unit)	$ 0.29	$ (0.12)	$ 0.30	$ (0.18)

Business Segment Information (N

Business Segment Information (Narrative) (Details)	9 Months Ended
	Sep. 30, 2023 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information (S

Business Segment Information (Schedule of Segment Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting Information [Line Items]
Total Segment Margin	$ 207,897	$ 196,190	$ 617,644	$ 572,914
Revenues	807,618	721,248	2,402,892	2,074,920
Preferred Distribution Rate Reset Election
Segment Reporting Information [Line Items]
Amount of Gain (Loss) Recognized in Income	12,300		17,700	(2,500)
Preferred Distribution Rate Reset Election | Other Expense [Member]
Segment Reporting Information [Line Items]
Amount of Gain (Loss) Recognized in Income		25,000
Offshore pipeline transportation
Segment Reporting Information [Line Items]
Revenues	106,297	89,805	289,151	239,958
Soda and sulfur services
Segment Reporting Information [Line Items]
Revenues	423,575	312,681	1,331,078	916,963
Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Revenues	197,526	240,967	541,874	708,110
Marine transportation
Segment Reporting Information [Line Items]
Revenues	80,220	77,795	240,789	209,889
Operating Segments
Segment Reporting Information [Line Items]
Total Segment Margin	207,897	196,190	617,644	572,914
Capital expenditures	205,183	151,768	419,553	313,470
Revenues	807,618	721,248	2,402,892	2,074,920
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total Segment Margin	109,267	91,402	300,505	281,286
Capital expenditures	149,489	86,893	293,187	166,703
Revenues	101,985	89,805	284,839	239,958
Operating Segments | Soda and sulfur services
Segment Reporting Information [Line Items]
Total Segment Margin	61,957	80,067	217,319	219,143
Capital expenditures	36,502	49,452	83,109	114,698
Revenues	425,913	315,334	1,337,897	924,534
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total Segment Margin	9,547	9,442	21,242	27,496
Capital expenditures	6,696	848	10,714	3,365
Revenues	199,500	238,483	539,367	700,909
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total Segment Margin	27,126	15,279	78,578	44,989
Capital expenditures	12,496	14,575	32,543	28,704
Revenues	80,220	77,626	240,789	209,519
Intersegment
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Intersegment | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Revenues	4,312	0	4,312	0
Intersegment | Soda and sulfur services
Segment Reporting Information [Line Items]
Revenues	(2,338)	(2,653)	(6,819)	(7,571)
Intersegment | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Revenues	(1,974)	2,484	2,507	7,201
Intersegment | Marine transportation
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 169	$ 0	$ 370

Business Segment Information _2

Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Segment Reporting Information [Line Items]
Total assets	$ 6,938,442	$ 6,365,992
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total assets	2,497,570	2,290,488
Operating Segments | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total assets	2,573,777	2,358,086
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total assets	1,146,639	981,354
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total assets	649,732	681,231
Other assets
Segment Reporting Information [Line Items]
Total assets	$ 70,724	$ 54,833

Business Segment Information (R

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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to Genesis Energy, L.P.		$ 58,070	$ 3,385	$ 105,770	$ 33,482
Corporate general and administrative expenses		18,329	18,132	52,580	54,958
Depreciation, depletion, amortization and accretion		71,099	76,301	(218,788)	(225,526)
Interest expense		61,580	57,710	184,057	168,773
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income(1)		6,387	5,247	(18,535)	(15,981)
Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value(2)		(12,299)	26,295	17,721	16,083
Other non-cash items		(7,228)	(1,659)	16,886	3,926
Distribution from unrestricted subsidiaries not included in income(3)		0	0	0	(32,000)
Cancellation of debt income		0	(3,881)	0	(8,619)
Cancellation of debt income					(8,618)
Loss on extinguishment of debt		0	(293)	1,812	794
Differences in timing of cash receipts for certain contractual arrangements(5)		11,385	13,775	33,519	38,482
Change in provision for leased items no longer in use		0	68	0	(599)
Gain on sale of asset, net to our ownership interest(7)		0	0	0	(32,000)
Income tax expense		574	660	1,748	1,535
Total Segment Margin		207,897	196,190	617,644	572,914
Net income attributable to redeemable noncontrolling interests		0	0	0	30,443
Unrealized (losses) gains from valuation of embedded derivatives				(17,721)	(15,726)
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			(32,000)
Alkali Holdings | Subsidiary
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to redeemable noncontrolling interests		$ 0	0	$ 0	30,443
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%		80%
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
Embedded Derivative Financial Instruments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Amount of Gain (Loss) Recognized in Income		$ 12,300		$ 17,700	(2,500)
Unrealized (losses) gains from valuation of embedded derivatives					$ 18,600
Embedded Derivative Financial Instruments | Other Nonoperating Income (Expense)
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Amount of Gain (Loss) Recognized in Income			1,300
Embedded Derivative Financial Instruments | Other Expense [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Amount of Gain (Loss) Recognized in Income			$ 25,000

Transactions with Related Par_3

Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Related Party Transaction [Line Items]
Revenues	$ 807,618	$ 721,248	$ 2,402,892	$ 2,074,920
Poseidon
Related Party Transaction [Line Items]
Equity method investment, ownership percentage	64%		64%
CEO
Related Party Transaction [Line Items]
Cost and expenses	$ 165	165	$ 495	495
Equity Method Investee
Related Party Transaction [Line Items]
Revenues	4,812	3,854	13,858	10,952
Cost and expenses	6,797	268	8,834	777
Other receivables	2,200		2,200		$ 2,400
Equity Method Investee | Fees
Related Party Transaction [Line Items]
Revenues	$ 2,500	$ 2,400	$ 7,500	$ 7,300

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
(Increase) decrease in:
Accounts receivable	$ 54,474	$ (170,635)
Inventories	(29,281)	(12,677)
Deferred charges	31,003	47,191
Other current assets	(4,571)	(4,717)
Increase (decrease) in:
Accounts payable	(31,006)	109,687
Accrued liabilities	(17,015)	(17,425)
Net changes in components of operating assets and liabilities	$ 3,604	$ (48,576)

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 196.3	$ 189.2
Interest paid, capitalized	29.2	11.2
Incurred liabilities for fixed and intangible asset additions	$ 121.4	$ 67.6

Derivatives (Schedule of Outsta

Derivatives (Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments) (Details) - 9 months ended Sep. 30, 2023 gal in Thousands, bbl in Thousands, T in Thousands, MMBTU in Thousands	bbl	$ / bbl	MMBTU	$ / MMBTU	T	$ / T	gal	$ / gal
Designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	398
Weighted average contract price | $ / bbl		80.23
Designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	192
Weighted average contract price | $ / bbl		82.51
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	59
Weighted average contract price | $ / bbl		84.75
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (bbls)	59
Contract volume (MMBTU) | MMBTU			180
Weighted average contract price		0.66		2.71
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (MT) | T					0
Weighted average contract price (MT) | $ / T						0
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 | Sell (Short) Contracts | Commodity Option | Natural Gas and Natural Gas Liquids
Derivative [Line Items]
Contract volumes (bbls) | gal							0
Weighted average contract price | $ / gal								0
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	33
Weighted average contract price | $ / bbl		90.34
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (bbls)	32
Contract volume (MMBTU) | MMBTU			1,294
Weighted average contract price		0.17		3.66
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (MT) | T					51,500
Weighted average contract price (MT) | $ / T						535.99
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swaps | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU			1,261
Weighted average contract price | $ / MMBTU				0.62
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Commodity Option | Natural Gas and Natural Gas Liquids
Derivative [Line Items]
Contract volumes (bbls) | gal							1,050
Weighted average contract price | $ / gal								0.27

Derivatives (Schedule of Fair V

Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 29, 2022
Derivatives, Fair Value [Line Items]
SENIOR UNSECURED NOTES, net of debt issuance costs and premium	$ 3,011,386	$ 2,856,312
Preferred Distribution Rate Reset Election
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability			$ (101,800)
Not qualifying or not designated as hedges under accounting rules | Commodity Derivatives
Derivatives, Fair Value [Line Items]
Asset Derivatives	0	0
Liability Derivatives	0	(5,844)
Not qualifying or not designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other(1)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,070	1,238
Derivative Asset, Fair Value, Gross Liability	(4,070)	(1,238)
Derivative Liability, Fair Value, Gross Liability	(6,546)	(11,061)
Derivative Liability, Fair Value, Gross Asset	6,546	5,217
Not qualifying or not designated as hedges under accounting rules | Swaps | Current Assets - Other(1)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	10,082	36,844
Not qualifying or not designated as hedges under accounting rules | Swaps | Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(2,695)	(4,692)
Designated as hedges under accounting rules | Commodity Derivatives
Derivatives, Fair Value [Line Items]
Asset Derivatives	0	0
Liability Derivatives	0	0
Designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other(1)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,304	0
Derivative Asset, Fair Value, Gross Liability	(1,304)	0
Derivative Liability, Fair Value, Gross Liability	(3,885)	0
Derivative Liability, Fair Value, Gross Asset	$ 3,885	$ 0

Derivatives (Narrative) (Detail

Derivatives (Narrative) (Details)				9 Months Ended	12 Months Ended
	Jan. 26, 2023 USD ($)	Jan. 25, 2023 USD ($)	Sep. 01, 2022	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	Sep. 29, 2022
Derivatives, Fair Value [Line Items]
Net broker receivable				$ 14,500,000	$ 4,000,000
Initial margin				7,200,000	3,800,000
Variation margin				$ 7,300,000	$ 200,000
Senior Notes | 5.625% senior unsecured notes due 2024
Derivatives, Fair Value [Line Items]
Repayments of long term debt	$ 24,800,000	$ 316,300,000
Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Period to notify holders			30 days
Stock reset rate percentage			10.75%		8.75%	11.24%
Percentage below issue price per share			110%
LIBOR | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price			0.0750			750
Stock reset rate percentage						3.74%

Derivatives (Schedule of Effect

Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Level 3 | Preferred Distribution Rate Reset Election
Derivative Instruments, Gain (Loss) [Line Items]
Preferred Distribution Rate Reset Election	$ 0	$ (24,977)	$ 0	$ (18,584)
Commodity derivatives - futures and call options
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(8,391)	9,223	(18,330)	16,967
Natural Gas Swap | Soda and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	8,600		15,086
Preferred Distribution Rate Reset Election
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	12,300		17,700	(2,500)
Contracts designated as hedges under accounting guidance | Commodity derivatives - futures and call options | Onshore facilities and transportation product costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(5,012)	2,085	(2,657)	1,549
Contracts not considered hedges under accounting guidance | Commodity derivatives - futures and call options | Onshore facilities and transportation product costs, Soda and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ (3,379)	7,138	$ (15,673)	15,418
Contracts not considered hedges under accounting guidance | Natural Gas Swap | Soda and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income		$ (489)		$ (2,181)

Fair-Value Measurements (Placem

Fair-Value Measurements (Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels) (Details) - Recurring Fair Value Measures - Commodity Derivatives - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 5,374	$ 1,238
Liabilities Fair Value	(10,431)	(11,061)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	10,082	36,844
Liabilities Fair Value	(2,695)	(4,692)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	$ 0	$ 0

Fair-Value Measurements (Narrat

Fair-Value Measurements (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying value of senior unsecured notes	$ 3,011,386	$ 2,856,312
Fair value of senior unsecured notes	2,900,000	2,700,000
Principal	3,658,149	$ 3,506,284
5.875% Alkali senior secured notes due 2042(2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Principal	$ 400,000

Uncategorized Items - gel-20230

Label	Element	Value
Amortization of Debt Issuance Costs and Discounts	us-gaap_AmortizationOfFinancingCostsAndDiscounts
Payments for (Proceeds from) Other Investing Activities	us-gaap_PaymentsForProceedsFromOtherInvestingActivities	$ 0