Genesis Energy (GEL) 10-Q 1 Aug 24 2024 Q2 Quarterly report Financial data

Cover

Cover - shares	6 Months Ended
	Jun. 30, 2024	Jul. 31, 2024
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2024
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	2024
Document Fiscal Period Focus	Q2
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	Jun. 30, 2024	Dec. 31, 2023
CURRENT ASSETS:
Cash and cash equivalents	$ 13,695	$ 9,234
Restricted cash	18,804	18,804
Accounts receivable - trade, net	687,985	759,547
Inventories	106,327	135,231
Other	38,805	41,234
Total current assets	865,616	964,050
FIXED ASSETS, at cost	6,665,271	6,500,897
Less: Accumulated depreciation	(2,090,138)	(1,972,596)
Net fixed assets	4,575,133	4,528,301
MINERAL LEASEHOLDS, net of accumulated depletion	538,034	540,520
EQUITY INVESTEES	252,142	263,829
INTANGIBLE ASSETS, net of amortization	141,748	141,537
GOODWILL	301,959	301,959
RIGHT OF USE ASSETS, net	231,710	240,341
OTHER ASSETS, net of amortization	44,960	38,241
TOTAL ASSETS	6,951,302	7,018,778
CURRENT LIABILITIES:
Accounts payable - trade	418,666	588,924
Accrued liabilities	375,254	378,523
Total current liabilities	793,920	967,447
SENIOR SECURED CREDIT FACILITY	134,800	298,300
SENIOR UNSECURED NOTES, net of debt issuance costs, discount and premium	3,416,804	3,062,955
DEFERRED TAX LIABILITIES	17,497	17,510
OTHER LONG-TERM LIABILITIES	557,857	570,197
Total liabilities	5,306,321	5,308,001
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 23,111,918 issued and outstanding at June 30, 2024 and December 31, 2023, respectively	$ 813,589	$ 813,589
Common units outstanding (in units)	122,464,318	122,464,318
PARTNERS’ CAPITAL:
Common unitholders, 122,464,318 units issued and outstanding at June 30, 2024 and December 31, 2023, respectively	$ 428,812	$ 519,698
Accumulated other comprehensive income	8,200	8,040
Noncontrolling interests	394,380	369,450
Total partners’ capital	831,392	897,188
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ 6,951,302	$ 7,018,778
Common units issued (in units)	122,464,318	122,464,318
Class A Convertible Preferred Stock Units
PARTNERS’ CAPITAL:
Number preferred units issued (in units)	23,111,918	23,111,918
5.875% Alkali senior secured notes due 2042(2)
CURRENT LIABILITIES:
SENIOR SECURED CREDIT FACILITY	$ 385,443	$ 391,592

UNAUDITED CONDENSED CONSOLIDA_2

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2024	Dec. 31, 2023
Common units issued (in units)	122,464,318	122,464,318
Common units outstanding (in units)	122,464,318	122,464,318
Class A Convertible Preferred Stock Units
Number preferred units issued (in units)	23,111,918	23,111,918

UNAUDITED CONDENSED CONSOLIDA_3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
REVENUES:
Total revenues	$ 756,261	$ 804,662	$ 1,526,366	$ 1,595,274
COSTS AND EXPENSES:
General and administrative	18,546	16,931	33,555	31,483
Depreciation, depletion and amortization	77,613	68,427	151,384	141,587
Total costs and expenses	697,540	701,878	1,395,587	1,443,109
OPERATING INCOME	58,721	102,784	130,779	152,165
Equity in earnings of equity investees	12,213	14,811	28,654	32,364
Interest expense, net	(70,870)	(61,623)	(139,604)	(122,477)
Other expense	(1,429)	(4)	(1,429)	(1,812)
Income (loss) from operations before income taxes	(1,365)	55,968	18,400	60,240
Income tax expense	(22)	(290)	(831)	(1,174)
NET INCOME (LOSS)	(1,387)	55,678	17,569	59,066
Net income attributable to noncontrolling interests	(7,357)	(6,334)	(14,960)	(11,366)
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.	(8,744)	49,344	2,609	47,700
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units	(21,894)	(22,910)	(43,788)	(46,912)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(30,638)	26,434	(41,179)	788
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (30,638)	$ 26,434	$ (41,179)	$ 788
Net Income (Loss), Per Outstanding Limited Partnership Unit, Basic, Net of Tax [Abstract]
Basic (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01
Diluted (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01
Earnings Per Unit [Abstract]
Basic (in units)	122,464	122,579	122,464	122,579
Diluted (in units)	122,464	122,579	122,464	122,579
Fee-based Revenues [Member]
REVENUES:
Total revenues	$ 199,325	$ 182,699	$ 400,182	$ 371,504
Offshore pipeline transportation
REVENUES:
Total revenues	99,024	91,459	201,014	182,854
Offshore pipeline transportation | Offshore Pipeline Transportation Revenue
REVENUES:
Total revenues	99,024	91,459	201,014	182,854
COSTS AND EXPENSES:
Cost of products and services sold	29,892	24,739	57,710	47,864
Offshore pipeline transportation | Fee-based Revenues [Member]
REVENUES:
Total revenues	99,024	91,459	201,014	182,854
Soda and sulfur services
REVENUES:
Total revenues	389,994	462,855	790,942	907,503
Soda and sulfur services | Sodium Minerals and Sulfur Services Revenue
REVENUES:
Total revenues	389,994	462,855	790,942	907,503
COSTS AND EXPENSES:
Cost of products and services sold	343,892	372,665	695,258	778,887
Soda and sulfur services | Fee-based Revenues [Member]
REVENUES:
Total revenues	0	0	0	0
Marine transportation
REVENUES:
Total revenues	81,871	77,343	165,445	160,569
Marine transportation | Marine Transportation Revenue
REVENUES:
Total revenues	81,871	77,343	165,445	160,569
COSTS AND EXPENSES:
Cost of products and services sold	50,602	51,848	103,010	109,584
Marine transportation | Fee-based Revenues [Member]
REVENUES:
Total revenues	81,871	77,343	165,445	160,569
Onshore facilities and transportation
REVENUES:
Total revenues	185,372	173,005	368,965	344,348
Onshore facilities and transportation | Onshore Facilities and Transportation Revenue
REVENUES:
Total revenues	185,372	173,005	368,965	344,348
Onshore facilities and transportation | Onshore Facilities and Transportation Product
COSTS AND EXPENSES:
Cost of products and services sold	159,155	149,429	319,543	298,485
Onshore facilities and transportation | Onshore Facilities and Transportation Services
COSTS AND EXPENSES:
Cost of products and services sold	17,840	17,839	35,127	35,219
Onshore facilities and transportation | Fee-based Revenues [Member]
REVENUES:
Total revenues	$ 18,430	$ 13,897	$ 33,723	$ 28,081

UNAUDITED CONDENSED CONSOLIDA_4

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Comprehensive Income [Abstract]
Net loss	$ (1,387)	$ 55,678	$ 17,569	$ 59,066
Other comprehensive income:
Decrease in benefit plan liability	80	121	160	243
Total Comprehensive income (loss)	(1,307)	55,799	17,729	59,309
Comprehensive income attributable to noncontrolling interests	(7,357)	(6,334)	(14,960)	(11,366)
Comprehensive income (loss) attributable to Genesis Energy, L.P.	$ (8,664)	$ 49,465	$ 2,769	$ 47,943

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, 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]
Net income (loss)	59,066	47,700		11,366
Cash distributions to partners	(36,774)	(36,774)
Cash distributions to noncontrolling interests	(22,223)			(22,223)
Cash contributions from noncontrolling interests	34,920			34,920
Other comprehensive income	243				243
Distributions to Class A Convertible Preferred unitholders	(46,912)	(46,912)
Partners' capital, ending balance (in shares) at Jun. 30, 2023			122,579
Partners' capital, ending balance at Jun. 30, 2023	871,873	531,291		334,225	6,357
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
Partners' capital, ending balance (in shares) at Dec. 31, 2023			122,464
Partners' capital, ending balance at Dec. 31, 2023	897,188	519,698		369,450	8,040
Partners' capital, beginning balance (in shares) at Mar. 31, 2023			122,579
Partners' capital, beginning balance at Mar. 31, 2023	848,749	523,244		319,269	6,236
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	55,678	49,344		6,334
Cash distributions to partners	(18,387)	(18,387)
Cash distributions to noncontrolling interests	(7,218)			(7,218)
Cash contributions from noncontrolling interests	15,840			15,840
Other comprehensive income	121				121
Distributions to Class A Convertible Preferred unitholders	(22,910)	(22,910)
Partners' capital, ending balance (in shares) at Jun. 30, 2023			122,579
Partners' capital, ending balance at Jun. 30, 2023	871,873	531,291		334,225	6,357
Partners' capital, beginning balance (in shares) at Dec. 31, 2023			122,464
Partners' capital, beginning balance at Dec. 31, 2023	897,188	519,698		369,450	8,040
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	17,569	2,609		14,960
Cash distributions to partners	(36,740)	(36,740)
Cash distributions to noncontrolling interests	(19,197)			(19,197)
Cash contributions from noncontrolling interests	16,200			16,200
Non-cash contribution to noncontrolling interests	0	(12,967)		12,967
Other comprehensive income	160				160
Distributions to Class A Convertible Preferred unitholders	(43,788)	(43,788)
Partners' capital, ending balance (in shares) at Jun. 30, 2024			122,464
Partners' capital, ending balance at Jun. 30, 2024	831,392	428,812		394,380	8,200
Partners' capital, beginning balance (in shares) at Mar. 31, 2024			122,464
Partners' capital, beginning balance at Mar. 31, 2024	874,853	490,787		375,946	8,120
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(1,387)	(8,744)		7,357
Cash distributions to partners	(18,370)	(18,370)
Cash distributions to noncontrolling interests	(9,090)			(9,090)
Cash contributions from noncontrolling interests	7,200			7,200
Non-cash contribution to noncontrolling interests	0	(12,967)		12,967
Other comprehensive income	80				80
Distributions to Class A Convertible Preferred unitholders	(21,894)	(21,894)
Partners' capital, ending balance (in shares) at Jun. 30, 2024			122,464
Partners' capital, ending balance at Jun. 30, 2024	$ 831,392	$ 428,812		$ 394,380	$ 8,200

UNAUDITED CONDENSED CONSOLIDA_6

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 17,569	$ 59,066
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation, depletion and amortization	151,384	141,587
Amortization and write-off of debt issuance costs, premium and discount	7,370	5,813
Equity in earnings of investments in equity investees	(28,654)	(32,364)
Cash distributions of earnings of equity investees	28,654	31,316
Non-cash effect of long-term incentive compensation plans	9,786	9,656
Deferred and other tax liabilities	(13)	551
Unrealized losses (gains) on derivative transactions	(10,941)	30,021
Other, net	6,255	8,718
Net changes in components of operating assets and liabilities (Note 15)	49,232	957
Net cash provided by operating activities	230,642	255,321
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(346,443)	(247,361)
Cash distributions received from equity investees - return of investment	11,687	13,300
Investments in equity investees	(285)	(2,197)
Proceeds from asset sales	10,996	202
Payments for (Proceeds from) Other Investing Activities	0
Net cash used in investing activities	(324,045)	(231,724)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	766,600	501,976
Repayments on senior secured credit facility	(930,100)	(573,776)
Proceeds from issuance of senior unsecured notes (Note 10)	700,000	500,000
Repayment of senior unsecured notes (Note 10)	(339,310)	(341,135)
Repayment of Alkali senior secured notes (Note 10)	(5,815)	0
Debt issuance costs	(13,252)	(14,269)
Contributions from noncontrolling interests	16,200	34,920
Distributions to noncontrolling interests	(19,197)	(22,223)
Distributions to common unitholders	(36,740)	(36,774)
Distributions to Class A Convertible Preferred unitholders	(43,788)	(48,019)
Redemption of Class A Convertible Preferred Units (Note 11)	0	(25,000)
Other, net	3,266	4,446
Net cash provided by (used in) financing activities	97,864	(19,854)
Net increase in cash, cash equivalents and restricted cash	4,461	3,743
Cash, cash equivalents and restricted cash at beginning of period	28,038	26,567
Cash, cash equivalents and restricted cash at end of period	$ 32,499	$ 30,310

Organization and Basis of Prese

Organization and Basis of Presentation and Consolidation	6 Months Ended
	Jun. 30, 2024
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 the 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”); • Marine transportation to provide waterborne transportation of petroleum products (primarily fuel oil, asphalt and other heavy refined products) and crude oil throughout North America; and • Onshore facilities and transportation, which includes terminaling, blending, storing, marketing, and transporting crude oil and petroleum products. 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, 2023 (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	6 Months Ended
	Jun. 30, 2024
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting Developments In November 2023, the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures” (“ASU 2023-07”), which enhances the disclosures required for operating segments in our annual and interim Consolidated Financial Statements. ASU 2023-07 is effective retrospectively for fiscal years beginning after December 15, 2023 and for interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. We are currently evaluating the impact of this standard on our disclosures. In December 2023, the Financial Accounting Standards Board (“FASB”) issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures” (“ASU 2023-09”), which is intended to enhance the transparency and usefulness of income tax disclosures. The amendments in ASU 2023-09 provide for enhanced income tax information primarily through changes to the rate reconciliation and income taxes paid information. ASU 2023-09 is effective prospectively to all annual periods beginning after December 15, 2024. Early adoption is permitted. We are currently evaluating the impact of this standard on our disclosures. All other new accounting pronouncements that have been issued, but not yet effective are currently being evaluated and at this time are not expected to have a material impact on our financial position or results of operations.

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2024
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 June 30, 2024 and 2023, respectively: Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 99,024 $ — $ 81,871 $ 18,430 $ 199,325 Product Sales — 369,568 — 166,942 536,510 Refinery Services — 20,426 — — 20,426 $ 99,024 $ 389,994 $ 81,871 $ 185,372 $ 756,261 Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities & Transportation Consolidated Fee-based revenues $ 91,459 $ — $ 77,343 $ 13,897 $ 182,699 Product Sales — 440,301 — 159,108 599,409 Refinery Services — 22,554 — — 22,554 $ 91,459 $ 462,855 $ 77,343 $ 173,005 $ 804,662 The following tables reflect the disaggregation of our revenues by major category for the six months ended June 30, 2024 and 2023, respectively: Six Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 201,014 $ — $ 165,445 $ 33,723 $ 400,182 Product Sales — 747,629 — 335,242 1,082,871 Refinery Services — 43,313 — — 43,313 $ 201,014 $ 790,942 $ 165,445 $ 368,965 $ 1,526,366 Six Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 182,854 $ — $ 160,569 $ 28,081 $ 371,504 Product Sales — 863,125 — 316,267 1,179,392 Refinery Services — 44,378 — — 44,378 $ 182,854 $ 907,503 $ 160,569 $ 344,348 $ 1,595,274 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, 2023 and June 30, 2024: Contract Assets Contract Liabilities Other Assets, net of amortization Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2023 $ 859 $ 11,460 $ 112,734 Balance at June 30, 2024 1,631 34,378 104,216 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 June 30, 2024. 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 2024 $ 70,508 $ 12,912 2025 151,333 25,853 2026 122,603 26,170 2027 77,482 13,864 2028 45,453 10,000 Thereafter 124,184 2,500 Total $ 591,563 $ 91,299

Business Consolidation

Business Consolidation	3 Months Ended
	Jun. 30, 2024
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. The allocation of the purchase price, as presented within our Condensed Consolidated Balance Sheet as of December 31, 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) Deferred tax liabilities (1,482) Other long-term liabilities (77,642) 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 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 the 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,” 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. We have reflected the financial results of ANSAC within our soda and sulfur services segment from the date of acquisition, January 1, 2023. The following financial information was prepared from our historical financial statements that have been adjusted to give the effect of the consolidation of ANSAC, and was prepared using financial data of ANSAC. Net income attributable to common unitholders includes the effects of distributions attributable to our Class A Convertible Preferred Units. The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Three Months Ended Six Months Ended Consolidated financial operating results: Revenues $ 804,662 $ 1,595,274 Net Income Attributable to Genesis Energy, L.P. 49,344 47,700 Net Income Attributable to Common Unitholders 26,434 788 Basic and diluted earnings per common unit: As reported net income per common unit $ 0.22 $ 0.01 Pro forma net income per common unit $ 0.22 $ 0.01

Lease Accounting

Lease Accounting	6 Months Ended
	Jun. 30, 2024
Leases [Abstract]
Lease Accounting	Lease Accounting Lessee Arrangements We lease a variety of transportation equipment (primarily railcars and vessels), 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). Certain of our leases contain options to extend the life of the lease at our sole discretion and 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, office space and equipment, and facilities and equipment leases. Additionally, it includes our unamortized prepaid rents and our deferred rents. 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 six months ended June 30, 2024 and 2023, we acted as a lessor in a revenue contract associated with our 330,000 barrel-capacity ocean going tanker, the M/T American Phoenix, included in our marine transportation segment. Our lease revenues for this arrangement were $7.1 million and $5.9 million for the three months ended June 30, 2024 and 2023, respectively, and $13.9 million and $11.7 million for the six months ended June 30, 2024 and 2023, respectively.
Lease Accounting	Lease Accounting Lessee Arrangements We lease a variety of transportation equipment (primarily railcars and vessels), 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). Certain of our leases contain options to extend the life of the lease at our sole discretion and 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, office space and equipment, and facilities and equipment leases. Additionally, it includes our unamortized prepaid rents and our deferred rents. 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 six months ended June 30, 2024 and 2023, we acted as a lessor in a revenue contract associated with our 330,000 barrel-capacity ocean going tanker, the M/T American Phoenix, included in our marine transportation segment. Our lease revenues for this arrangement were $7.1 million and $5.9 million for the three months ended June 30, 2024 and 2023, respectively, and $13.9 million and $11.7 million for the six months ended June 30, 2024 and 2023, respectively.

Inventories

Inventories	6 Months Ended
	Jun. 30, 2024
Inventory Disclosure [Abstract]
Inventories	Inventories The major components of inventories were as follows: June 30, 2024 December 31, 2023 Crude oil $ 22,318 $ 22,320 Caustic soda 7,198 9,150 NaHS 12,199 17,605 Raw materials - Alkali Business 10,872 8,355 Work-in-process - Alkali Business 7,652 11,404 Finished goods, net - Alkali Business 26,684 48,706 Materials and supplies, net - Alkali Business 19,404 17,691 Total $ 106,327 $ 135,231 Inventories are valued at the lower of cost or net realizable value. As of June 30, 2024 and December 31, 2023, the net realizable value of inventories were below their respective cost by $0.1 million and $0.2 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	6 Months Ended
	Jun. 30, 2024
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: June 30, 2024 December 31, 2023 Crude oil and natural gas pipelines and related assets $ 2,953,262 $ 2,945,215 Alkali facilities, machinery and equipment 1,163,200 1,147,291 Onshore facilities, machinery and equipment 291,039 271,271 Transportation equipment 30,588 24,913 Marine vessels 1,024,287 1,021,080 Land, buildings and improvements 296,424 293,733 Office equipment, furniture and fixtures 25,268 25,029 Construction in progress (1) 851,892 731,197 Other 29,311 41,168 Fixed assets, at cost 6,665,271 6,500,897 Less: Accumulated depreciation (2,090,138) (1,972,596) Net fixed assets $ 4,575,133 $ 4,528,301 (1) Construction in progress primarily relates to our ongoing offshore growth capital projects, which are expected to be completed in late 2024 and in 2025, and represents 100% of the costs incurred, including those funded by our noncontrolling interest holder. Mineral Leaseholds Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: June 30, 2024 December 31, 2023 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (27,985) (25,499) Mineral leaseholds, net of accumulated depletion $ 538,034 $ 540,520 Our depreciation and depletion expense for the periods presented were as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Depreciation expense $ 73,341 $ 63,913 $ 143,026 $ 133,486 Depletion expense 1,340 1,268 2,486 2,149 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, 2023: ARO liability balance, December 31, 2023 $ 243,708 Accretion expense 5,554 Settlements (298) ARO liability balance, June 30, 2024 $ 248,964 At June 30, 2024 and December 31, 2023, $26.1 million is included as current in “Accrued liabilities” on our Unaudited Condensed Consolidated Balance Sheets. The remainder of the ARO liability as of June 30, 2024 and December 31, 2023 is included in “Other long-term liabilities” on our Unaudited Condensed Consolidated Balance Sheets. Certain of our unconsolidated affiliates have AROs recorded at June 30, 2024 and December 31, 2023 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	6 Months Ended
	Jun. 30, 2024
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 the underlying book value of the capital accounts we acquire. Such excess cost amounts are included within the carrying values of our equity investees. At June 30, 2024 and December 31, 2023, the unamortized excess cost amounts totaled $284.2 million and $291.4 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 Six Months Ended 2024 2023 2024 2023 Genesis’ share of operating earnings $ 15,779 $ 18,377 $ 35,786 $ 39,496 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,566) (7,132) (7,132) Equity in earnings of equity investees $ 12,213 $ 14,811 $ 28,654 $ 32,364 Distributions received (1) $ 17,092 $ 20,678 $ 40,341 $ 44,512 (1) Distributions attributab le to the respective period and received within 15 days subsequent to the respective period end. Poseidon’s Revolving Credit Facility Poseidon Oil Pipeline Company, LLC (“Poseidon”) has a revolving credit facility , which was amended and restated on June 1, 2023 (the “June 2023 credit facility”). Borrowings under Poseidon’s revolving credit facility have historically been used to fund spending on capital projects and for working capital needs, if necessary. 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	6 Months Ended
	Jun. 30, 2024
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets The following table summarizes the components of our intangible assets at the dates indicated: June 30, 2024 December 31, 2023 Gross Accumulated Carrying Gross Accumulated Carrying Offshore pipeline contract intangibles $ 158,101 $ 74,196 $ 83,905 $ 158,101 $ 70,036 $ 88,065 Other 76,845 19,002 57,843 70,974 17,502 53,472 Total $ 234,946 $ 93,198 $ 141,748 $ 229,075 $ 87,538 $ 141,537 Our amortization of intangible assets for the periods presented was as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Amortization of intangible assets $ 2,826 $ 2,973 $ 5,660 $ 5,678 We estimate that our amortization expense for the next five years will be as follows: Remainder of 2024 $ 5,583 2025 15,152 2026 14,840 2027 14,393 2028 14,144

Debt

Debt	6 Months Ended
	Jun. 30, 2024
Debt Disclosure [Abstract]
Debt	Senior Secured Credit Facility On February 17, 2023, we entered into the Sixth Amended and Restated Credit Agreement (our “credit agreement”) to replace our Fifth Amended and Restated Credit Agreement. Our credit agreement provides for a $850 million senior secured revolving credit facility. The credit agreement matures on February 13, 2026, subject to extension at our request for one At June 30, 2024, the key terms for rates under our senior secured credit facility (which are dependent on our leverage ratio as defined in the credit agreement) are as follows: • The interest rate on borrowings may be based on an alternate base rate or Term Secured Overnight Financing Rate (“SOFR”), at our option. Interest on alternate base rate loans is equal to the sum of (a) the highest of (i) the prime rate in effect on such day, (ii) the federal funds effective rate in effect on such day plus 0.5% and (iii) the Adjusted Term SOFR (as defined in our credit agreement) for a one-month tenor in effect on such day plus 1% and (b) the applicable margin. The Adjusted Term SOFR is equal to the sum of (a) the Term SOFR rate (as defined in our credit agreement) 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 June 30, 2024, the applicable margins on our borrowings were 2.00% for alternate base rate borrowings and 3.00% for Term SOFR borrowings based on our leverage ratio. • Letter of credit fee rates range from 2.25% to 3.50% based on our leverage ratio as computed under the credit agreement and can fluctuate quarterly. At June 30, 2024, our letter of credit rate was 3.00%. • 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 June 30, 2024, 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 June 30, 2024, we had $134.8 million borrowed under our senior secured credit facility, with $17.2 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 $4.5 million was outstanding at June 30, 2024. 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 June 30, 2024 was $710.7 million, subject to compliance with covenants. Our credit agreement does not include a “borrowing base” limitation except with respect to our inventory loans. Alkali Senior Secured Notes Issuance The agreement governing our 5.875% senior secured notes due 2042 (the “Alkali senior secured notes”) requires principal repayments on the last day of each quarter commencing with the quarter ended March 31, 2024. We made principal payments on our Alkali senior secured notes of $2.8 million and $5.8 million for three and six months ending June 30, 2024, respectively. As of June 30, 2024, principal repayments totaling $71.9 million are due within the next five years, with the remaining quarterly principal repayments due thereafter through March 31, 2042. As of June 30, 2024, $12.3 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, LLC (“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 June 30, 2024, our liquidity reserve account had a balance of $18.8 million, which is classified as “Restricted cash” on the Unaudited Condensed Consolidated Balance Sheet. Senior Unsecured Note Transactions On May 9, 2024, we issued $700.0 million in aggregate principal amount of 7.875% senior unsecured notes due May 15, 2032 (the “2032 Notes”). Interest payments are due May 15 and November 15 of each year with the initial interest payment due on November 15, 2024. The issuance of our 2032 Notes generated net proceeds of approximately $688 million, net of issuance costs incurred. The net proceeds were used to redeem $339.3 million of our existing 6.25% senior unsecured notes due May 15, 2026 (the “2026 Notes”) and pay the related accrued interest. The remaining proceeds were used to repay a portion of the borrowing outstanding under our senior secured credit facility, and for general partnership purposes. We incurred a loss of $1.4 million associated with the write-off of the related unamortized debt issuance costs on our 2026 Notes, which is recorded as “Other expense” in our Unaudited Condensed Consolidated Statement of Operations for the three and six months ended June 30, 2024. 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 issuance generated net proceeds of approximately $491 million, net of issuance costs incurred. The net proceeds were used to purchase $316.3 million of our existing 5.625% senior unsecured notes due June 15, 2024 (the “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. We incurred a loss of $1.8 million on the tender and redemption of the 2024 Notes, inclusive of our transactions costs and write-off of the related unamortized debt issuance costs, which is recorded as “Other expense” in our Unaudited Condensed Consolidated Statement of Operations for the six months ended June 30, 2023. Our $3.5 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 GA ORRI’s fifty-year limited term 10% overriding royalty interest in substantially all of the Alkali Business’ trona mineral leases (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	6 Months Ended
	Jun. 30, 2024
Equity [Abstract]
Partners' Capital, Mezzanine Capital and Distributions	Partners’ Capital, Mezzanine Capital and Distributions At June 30, 2024, 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 June 30, 2024, we had 23,111,918 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 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. We did not repurchase any Class A Common Units in 2024. Distributions We paid, or will pay, the following cash distributions to our common unitholders in 2023 and 2024: Distribution For Date Paid Per Unit Total 2023 1 st Quarter May 15, 2023 $ 0.15 $ 18,387 2 nd Quarter August 14, 2023 $ 0.15 $ 18,387 3 rd Quarter November 14, 2023 $ 0.15 $ 18,370 4 th Quarter February 14, 2024 $ 0.15 $ 18,370 2024 1 st Quarter May 15, 2024 $ 0.15 $ 18,370 2 nd Quarter (1) August 14, 2024 $ 0.15 $ 18,370 (1) This distribution was declared in July 2024 and will be paid to unitholders of record as of July 31, 2024. 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. On April 3, 2023, we entered into a purchase agreement with the Class A Convertible Preferred unitholders whereby we redeemed 741,620 Class A Convertible Preferred Units (the “Redeemed Units”) at a purchase price of $33.71 per unit. The Redeemed Units had a carrying value of $35.20 per unit resulting in a return attributable to the Class A Convertible Preferred Units of approximately $1.1 million. Net Income (Loss) 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 (Loss) Attributable to Genesis Energy, L.P. was reduced by $21.9 million and $43.8 million for the three and six months ending June 30, 2024, respectively, and $24.0 million and $48.0 million for the three and six months ending June 30, 2023 , 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 six months ended June 30, 2023, Net Income Attributable to Genesis Energy L.P. was increased by $1.1 million due to returns attributable to the Class A Convertible Preferred Units accumulated in the period. As of June 30, 2024, 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 2023 and 2024: Distribution For Date Paid Per Unit Total 2023 1 st Quarter May 15, 2023 $ 0.9473 $ 24,002 2 nd Quarter August 14, 2023 $ 0.9473 $ 23,314 3 rd Quarter November 14, 2023 $ 0.9473 $ 22,612 4 th Quarter February 14, 2024 $ 0.9473 $ 21,894 2024 1 st Quarter May 15, 2024 $ 0.9473 $ 21,894 2 nd Quarter (1) August 14, 2024 $ 0.9473 $ 21,894 (1) This distribution was declared in July 2024 and will be paid to unitholders of record as of July 31, 2024 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	6 Months Ended
	Jun. 30, 2024
Net Income per Common Unit [Abstract]
Net Loss Per Common Unit	Net Income (Loss) Per Common Unit Basic net income (loss) per common unit is computed by dividing net income (loss) attributable to Genesis Energy, L.P., after considering income attributable to our Class A preferred unitholders, by the weighted average number of common units outstanding. The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Under the if-converted method, the Class A Convertible Preferred Units are assumed to be converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted net income (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 six months ended June 30, 2024 and 2023, 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 (loss) 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 Six Months Ended 2024 2023 2024 2023 Net income (loss) attributable to Genesis Energy, L.P. $ (8,744) $ 49,344 $ 2,609 $ 47,700 Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units (21,894) (22,910) (43,788) (46,912) Net income (loss) attributable to common unitholders $ (30,638) $ 26,434 $ (41,179) $ 788 Weighted average outstanding units 122,464 122,579 122,464 122,579 Basic and diluted net income (loss) per common unit $ (0.25) $ 0.22 $ (0.34) $ 0.01

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 30, 2024
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”); • Marine transportation to provide waterborne transportation of petroleum products (primarily fuel oil, asphalt and other heavy refined products) and crude oil throughout North America; and • Onshore facilities and transportation, which includes terminaling, blending, storing, marketing, and transporting crude oil and petroleum products. 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	6 Months Ended
	Jun. 30, 2024
Related Party Transactions [Abstract]
Transactions with Related Parties	Transactions with Related Parties The transactions with related parties were as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Revenues: Revenues from services and fees to Poseidon (1) $ 6,025 $ 5,454 $ 11,008 $ 9,046 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 $ 330 $ 330 Charges for products purchased from Poseidon (1) 298 1,755 584 2,037 (1) We own a 64% interest in Poseidon. Our CEO, Mr. Grant E. 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 would expect to obtain in an arms-length transaction. Transactions with Unconsolidated Affiliates Poseidon

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2024
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. Six Months Ended 2024 2023 (Increase) decrease in: Accounts receivable $ 73,043 $ 147,999 Inventories 40,761 (20,187) Deferred charges 6,497 21,076 Other current assets 10,696 (129) Increase (decrease) in: Accounts payable (68,308) (130,131) Accrued liabilities (13,457) (17,671) Net changes in components of operating assets and liabilities $ 49,232 $ 957 Payments of interest and commitment fees were $126.0 million and $117.5 million for the six months ended June 30, 2024 and 2023, respectively. We capitalized interest of $23.3 million and $18.3 million during the six months ended June 30, 2024 and June 30, 2023, respectively. At June 30, 2024 and 2023, we had incurred liabilities for fixed and intangible asset additions totaling $43.2 million and $64.0 million, respectively, that had not been paid at the end of the quarter. Therefore, these amounts were not included in the caption “Payments to acquire fixed and intangible assets” under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows. The amounts as of June 30, 2024 primarily relate to the capital expenditures associated with our offshore growth capital projects.

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2024
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 June 30, 2024, we had a net broker receivable of approximately $13.0 million (consisting of initial margin of $4.3 million increased by $8.7 million variation margin). As of December 31, 2023, we had a net broker receivable of approximately $10.9 million (consisting of initial margin of $5.7 million increased by $5.2 million of variation margin). At June 30, 2024 and December 31, 2023, 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 June 30, 2024, 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) 249 — Weighted average contract price per Bbl $ 78.32 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 32 53 Weighted average contract price per Bbl $ 80.72 $ 79.66 Natural gas swaps: Contract volumes (10,000 MMBtu) — 767 Weighted average price differential per MMBtu $ — $ 0.42 Natural gas futures: Contract volumes (10,000 MMBtu) 250 943 Weighted average contract price per MMBtu $ 2.80 $ 3.54 Natural gas options: Contract volumes (10,000 MMBtu) 16 5 Weighted average premium received/paid $ 0.26 $ 0.06 Bunker fuel futures: Contract volumes (metric tons “MT”) — 60,500 Weighted average price per MT $ — $ 540.17 Bunker fuel swaps: Contract volumes (metric tons “MT”) — 8,500 Weighted average price per MT $ — $ 553.14 DOE diesel options: Contract volumes (1,000 Gal) — 1,950 Weighted average premium received/paid $ — $ 0.35 Fair Value of Derivative Assets and Liabilities The following tables reflect the estimated fair value position of our derivatives at June 30, 2024 and December 31, 2023: Unaudited Condensed Consolidated Balance Sheets Location Fair Value June 30, 2024 December 31, 2023 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Accounts receivable - trade, net $ 4,735 $ 3,710 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other (1) $ 2,718 $ 1,235 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (2,718) (1,235) 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) $ 409 $ 716 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (409) (716) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Liability Derivatives: Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued liabilities $ (4,160) $ (5,536) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (5,326) $ (12,384) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 5,326 12,384 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (1,153) $ (120) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 1,153 120 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”. Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended Six Months Ended 2024 2023 2024 2023 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (59) $ 1,388 $ (2,977) $ 2,355 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Soda and sulfur services operating costs 499 (2,141) 1,387 (12,294) Total commodity derivatives $ 440 $ (753) $ (1,590) $ (9,939) Natural Gas Swap Soda and sulfur services operating costs $ (1,891) $ (7,599) $ 1,119 $ 6,486

Fair-Value Measurements

Fair-Value Measurements	6 Months Ended
	Jun. 30, 2024
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 June 30, 2024 and December 31, 2023. June 30, 2024 December 31, 2023 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 3,127 $ 4,735 $ — $ 1,951 $ 3,710 $ — Liabilities $ (6,479) $ (4,160) $ — $ (12,504) $ (5,536) $ — 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 June 30, 2024. 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 June 30, 2024 and December 31, 2023, our senior unsecured notes had a carrying value of approximately $3.5 billion and $3.1 billion, respectively, and a fair value of approximately $3.5 billion and $3.2 billion, respectively. 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 June 30, 2024 and December 31, 2023, our Alkali senior secured notes had a carrying value and fair value of approximately $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	6 Months Ended
	Jun. 30, 2024
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.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2024
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On July 19, 2024, we entered into the Seventh Amended and Restated Credit Agreement (our “new credit agreement”) to replace our Sixth Amended and Restated Credit Agreement. Our new credit agreement provides for a $900 million senior secured revolving credit facility that matures on September 1, 2028, subject to extension at our request for one

Recent Accounting Developments

Recent Accounting Developments (Policies)	6 Months Ended
	Jun. 30, 2024
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, 2023 (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	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2024
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 June 30, 2024 and 2023, respectively: Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 99,024 $ — $ 81,871 $ 18,430 $ 199,325 Product Sales — 369,568 — 166,942 536,510 Refinery Services — 20,426 — — 20,426 $ 99,024 $ 389,994 $ 81,871 $ 185,372 $ 756,261 Three Months Ended Offshore Pipeline Transportation Soda and Sulfur Services Marine Transportation Onshore Facilities & Transportation Consolidated Fee-based revenues $ 91,459 $ — $ 77,343 $ 13,897 $ 182,699 Product Sales — 440,301 — 159,108 599,409 Refinery Services — 22,554 — — 22,554 $ 91,459 $ 462,855 $ 77,343 $ 173,005 $ 804,662 The following tables reflect the disaggregation of our revenues by major category for the six months ended June 30, 2024 and 2023, respectively:
Schedule of Contract Asset and Liabilities Balances Activity		The table below depicts our contract asset and liability balances at December 31, 2023 and June 30, 2024: Contract Assets Contract Liabilities Other Assets, net of amortization Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2023 $ 859 $ 11,460 $ 112,734 Balance at June 30, 2024 1,631 34,378 104,216
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 2024 $ 70,508 $ 12,912 2025 151,333 25,853 2026 122,603 26,170 2027 77,482 13,864 2028 45,453 10,000 Thereafter 124,184 2,500 Total $ 591,563 $ 91,299

Business Consolidation (Tables)

Business Consolidation (Tables)	3 Months Ended	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2024
Business Combination and Asset Acquisition [Abstract]
Summary of Unaudited Consolidated Balance Sheet and Statements of Operations	The allocation of the purchase price, as presented within our Condensed Consolidated Balance Sheet as of December 31, 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) Deferred tax liabilities (1,482) Other long-term liabilities (77,642) Net Assets $ — (1)
Schedule of Pro Forma Financial Information		The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Three Months Ended Six Months Ended Consolidated financial operating results: Revenues $ 804,662 $ 1,595,274 Net Income Attributable to Genesis Energy, L.P. 49,344 47,700 Net Income Attributable to Common Unitholders 26,434 788 Basic and diluted earnings per common unit: As reported net income per common unit $ 0.22 $ 0.01 Pro forma net income per common unit $ 0.22 $ 0.01

Inventories (Tables)

Inventories (Tables)	6 Months Ended
	Jun. 30, 2024
Inventory Disclosure [Abstract]
Schedule of Major Components of Inventories	The major components of inventories were as follows: June 30, 2024 December 31, 2023 Crude oil $ 22,318 $ 22,320 Caustic soda 7,198 9,150 NaHS 12,199 17,605 Raw materials - Alkali Business 10,872 8,355 Work-in-process - Alkali Business 7,652 11,404 Finished goods, net - Alkali Business 26,684 48,706 Materials and supplies, net - Alkali Business 19,404 17,691 Total $ 106,327 $ 135,231

Fixed Assets, Mineral Leaseho_2

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2024
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule of Fixed Assets	Fixed assets consisted of the following: June 30, 2024 December 31, 2023 Crude oil and natural gas pipelines and related assets $ 2,953,262 $ 2,945,215 Alkali facilities, machinery and equipment 1,163,200 1,147,291 Onshore facilities, machinery and equipment 291,039 271,271 Transportation equipment 30,588 24,913 Marine vessels 1,024,287 1,021,080 Land, buildings and improvements 296,424 293,733 Office equipment, furniture and fixtures 25,268 25,029 Construction in progress (1) 851,892 731,197 Other 29,311 41,168 Fixed assets, at cost 6,665,271 6,500,897 Less: Accumulated depreciation (2,090,138) (1,972,596) Net fixed assets $ 4,575,133 $ 4,528,301
Schedule of Mineral Leaseholds	Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: June 30, 2024 December 31, 2023 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (27,985) (25,499) Mineral leaseholds, net of accumulated depletion $ 538,034 $ 540,520
Schedule of Depreciation and Depletion Expense	Our depreciation and depletion expense for the periods presented were as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Depreciation expense $ 73,341 $ 63,913 $ 143,026 $ 133,486 Depletion expense 1,340 1,268 2,486 2,149
Schedule of Change in Asset Retirement Obligation	The following table presents information regarding our AROs since December 31, 2023: ARO liability balance, December 31, 2023 $ 243,708 Accretion expense 5,554 Settlements (298) ARO liability balance, June 30, 2024 $ 248,964

Equity Investees (Tables)

Equity Investees (Tables)	6 Months Ended
	Jun. 30, 2024
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 Six Months Ended 2024 2023 2024 2023 Genesis’ share of operating earnings $ 15,779 $ 18,377 $ 35,786 $ 39,496 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,566) (7,132) (7,132) Equity in earnings of equity investees $ 12,213 $ 14,811 $ 28,654 $ 32,364 Distributions received (1) $ 17,092 $ 20,678 $ 40,341 $ 44,512 (1) Distributions attributab

Intangible Assets (Tables)

Intangible Assets (Tables)	6 Months Ended
	Jun. 30, 2024
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: June 30, 2024 December 31, 2023 Gross Accumulated Carrying Gross Accumulated Carrying Offshore pipeline contract intangibles $ 158,101 $ 74,196 $ 83,905 $ 158,101 $ 70,036 $ 88,065 Other 76,845 19,002 57,843 70,974 17,502 53,472 Total $ 234,946 $ 93,198 $ 141,748 $ 229,075 $ 87,538 $ 141,537
Schedule of Amortization Expense	Our amortization of intangible assets for the periods presented was as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Amortization of intangible assets $ 2,826 $ 2,973 $ 5,660 $ 5,678
Schedule of Expected Amortization Expense	We estimate that our amortization expense for the next five years will be as follows: Remainder of 2024 $ 5,583 2025 15,152 2026 14,840 2027 14,393 2028 14,144

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2024
Debt Disclosure [Abstract]
Schedule of Debt	Our obligations under debt arrangements consisted of the following: June 30, 2024 December 31, 2023 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) $ 134,800 $ — $ 134,800 $ 298,300 $ — $ 298,300 6.250% senior unsecured notes due 2026 — — — 339,310 1,746 337,564 8.000% senior unsecured notes due 2027 981,245 2,888 978,357 981,245 3,549 977,696 7.750% senior unsecured notes due 2028 679,360 5,372 673,988 679,360 6,121 673,239 8.250% senior unsecured notes due 2029 600,000 15,610 584,390 600,000 17,202 582,798 8.875% senior unsecured notes due 2030 500,000 7,678 492,322 500,000 8,342 491,658 7.875% senior unsecured notes due 2032 700,000 12,253 687,747 — — — 5.875% Alkali senior secured notes due 2042 (2) 419,185 21,395 397,790 425,000 21,791 403,209 Total long-term debt $ 4,014,590 $ 65,196 $ 3,949,394 $ 3,823,215 $ 58,751 $ 3,764,464 (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 $4.3 million and $5.7 million as of June 30, 2024 and December 31, 2023, respectively. (2) As of June 30, 2024 and December 31, 2023, $12.3 million and $11.6 million, respectively, of the principal balance is considered current and included within “Accrued liabilities” on the Unaudited Condensed Consolidated Balance Sheets.

Partners' Capital, Mezzanine _2

Partners' Capital, Mezzanine Capital and Distributions (Tables)	6 Months Ended
	Jun. 30, 2024
Equity [Abstract]
Schedule of Paid Distributions	We paid, or will pay, the following cash distributions to our common unitholders in 2023 and 2024: Distribution For Date Paid Per Unit Total 2023 1 st Quarter May 15, 2023 $ 0.15 $ 18,387 2 nd Quarter August 14, 2023 $ 0.15 $ 18,387 3 rd Quarter November 14, 2023 $ 0.15 $ 18,370 4 th Quarter February 14, 2024 $ 0.15 $ 18,370 2024 1 st Quarter May 15, 2024 $ 0.15 $ 18,370 2 nd Quarter (1) August 14, 2024 $ 0.15 $ 18,370 (1) This distribution was declared in July 2024 and will be paid to unitholders of record as of July 31, 2024. We paid, or will pay, by the dates noted below, the following cash distributions to our Class A Convertible Preferred unitholders in 2023 and 2024: Distribution For Date Paid Per Unit Total 2023 1 st Quarter May 15, 2023 $ 0.9473 $ 24,002 2 nd Quarter August 14, 2023 $ 0.9473 $ 23,314 3 rd Quarter November 14, 2023 $ 0.9473 $ 22,612 4 th Quarter February 14, 2024 $ 0.9473 $ 21,894 2024 1 st Quarter May 15, 2024 $ 0.9473 $ 21,894 2 nd Quarter (1) August 14, 2024 $ 0.9473 $ 21,894 (1) This distribution was declared in July 2024 and will be paid to unitholders of record as of July 31, 2024

Net Loss Per Common Unit (Table

Net Loss Per Common Unit (Tables)	6 Months Ended
	Jun. 30, 2024
Net Income per Common Unit [Abstract]
Schedule of Computation of Earnings Per Share, Basic and Diluted	The following table reconciles net income (loss) attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net income (loss) per common unit (in thousands): Three Months Ended Six Months Ended 2024 2023 2024 2023 Net income (loss) attributable to Genesis Energy, L.P. $ (8,744) $ 49,344 $ 2,609 $ 47,700 Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units (21,894) (22,910) (43,788) (46,912) Net income (loss) attributable to common unitholders $ (30,638) $ 26,434 $ (41,179) $ 788 Weighted average outstanding units 122,464 122,579 122,464 122,579 Basic and diluted net income (loss) per common unit $ (0.25) $ 0.22 $ (0.34) $ 0.01

Business Segment Information (T

Business Segment Information (Tables)	6 Months Ended
	Jun. 30, 2024
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 Marine Transportation Onshore Facilities and Transportation Total Three Months Ended June 30, 2024 Segment Margin (1) $ 86,131 $ 41,611 $ 31,543 $ 9,028 $ 168,313 Capital expenditures (2) $ 55,788 $ 18,106 $ 29,532 $ 6,692 $ 110,118 Revenues: External customers $ 99,024 $ 392,226 $ 81,871 $ 183,140 $ 756,261 Intersegment (3) — (2,232) — 2,232 — Total revenues of reportable segments $ 99,024 $ 389,994 $ 81,871 $ 185,372 $ 756,261 Three Months Ended June 30, 2023 Segment Margin (1) $ 93,300 $ 89,255 $ 25,758 $ 6,305 $ 214,618 Capital expenditures (2) $ 91,645 $ 26,622 $ 10,990 $ 2,088 $ 131,345 Revenues: External customers $ 91,459 $ 465,077 $ 77,343 $ 170,783 $ 804,662 Intersegment (3) — (2,222) — 2,222 — Total revenues of reportable segments $ 91,459 $ 462,855 $ 77,343 $ 173,005 $ 804,662 Six Months Ended June 30, 2024 Segment Margin (1) $ 183,937 $ 86,993 $ 62,906 $ 15,575 $ 349,411 Capital expenditures (2) $ 119,414 $ 36,706 $ 41,842 $ 13,213 $ 211,175 Revenues: External customers $ 201,014 $ 795,179 $ 165,445 $ 364,728 $ 1,526,366 Intersegment (3) — (4,237) — 4,237 — Total revenues of reportable segments $ 201,014 $ 790,942 $ 165,445 $ 368,965 $ 1,526,366 Six Months Ended June 30, 2023 Segment Margin (1) $ 191,238 $ 155,362 $ 51,452 $ 11,695 $ 409,747 Capital expenditures (2) $ 143,698 $ 46,607 $ 20,047 $ 4,018 $ 214,370 Revenues: External customers $ 182,854 $ 911,983 $ 160,569 $ 339,868 $ 1,595,274 Intersegment (3) — (4,480) — 4,480 — Total revenues of reportable segments $ 182,854 $ 907,503 $ 160,569 $ 344,348 $ 1,595,274 (1) A reconciliation of Net income (loss) attributable to Genesis Energy, L.P. to total Segment Margin for the periods is presented below. (2) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as contributions to equity investees, if any. (3) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions. Total assets by reportable segment were as follows: June 30, 2024 December 31, 2023 Offshore pipeline transportation $ 2,653,561 $ 2,580,032 Soda and sulfur services 2,616,451 2,705,350 Marine transportation 639,386 645,020 Onshore facilities and transportation 965,850 1,019,113 Other assets 76,054 69,263 Total consolidated assets $ 6,951,302 $ 7,018,778
Reconciliation of Segment Margin to (Loss) Income from Continuing Operations	Reconciliation of Net income (loss) attributable to Genesis Energy, L.P. to total Segment Margin: Three Months Ended Six Months Ended 2024 2023 2024 2023 Net income (loss) attributable to Genesis Energy, L.P. $ (8,744) $ 49,344 $ 2,609 $ 47,700 Corporate general and administrative expenses 20,007 18,487 36,056 34,251 Depreciation, depletion, amortization and accretion 80,386 71,754 156,929 147,689 Interest expense, net 70,870 61,623 139,604 122,477 Adjustment to include distributable cash generated by equity investees not included in income and exclude equity in investees net income (1) 4,879 5,867 11,687 12,148 Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value (5,860) 2,888 (10,941) 30,020 Other non-cash items (2,496) (7,197) (4,685) (9,658) Loss on extinguishment of debt (2) 1,429 3 1,429 1,812 Differences in timing of cash receipts for certain contractual arrangements (3) 7,820 11,559 15,892 22,134 Income tax expense 22 290 831 1,174 Total Segment Margin $ 168,313 $ 214,618 $ 349,411 $ 409,747 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The three and six months ended June 30, 2024 includes the write-off of the unamortized issuance costs associated with the redemption of our 2026 Notes. The three and six months ended June 30, 2023 includes transactions costs and the write-off of the related unamortized debt issuance costs associated with the tender and redemption of our 2024 Notes. (3) 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.

Transactions with Related Par_2

Transactions with Related Parties (Tables)	6 Months Ended
	Jun. 30, 2024
Related Party Transactions [Abstract]
Schedule Of Transactions with Related Parties	The transactions with related parties were as follows: Three Months Ended Six Months Ended 2024 2023 2024 2023 Revenues: Revenues from services and fees to Poseidon (1) $ 6,025 $ 5,454 $ 11,008 $ 9,046 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 $ 330 $ 330 Charges for products purchased from Poseidon (1) 298 1,755 584 2,037 (1)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2024
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. Six Months Ended 2024 2023 (Increase) decrease in: Accounts receivable $ 73,043 $ 147,999 Inventories 40,761 (20,187) Deferred charges 6,497 21,076 Other current assets 10,696 (129) Increase (decrease) in: Accounts payable (68,308) (130,131) Accrued liabilities (13,457) (17,671) Net changes in components of operating assets and liabilities $ 49,232 $ 957

Derivatives (Tables)

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments	At June 30, 2024, 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) 249 — Weighted average contract price per Bbl $ 78.32 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 32 53 Weighted average contract price per Bbl $ 80.72 $ 79.66 Natural gas swaps: Contract volumes (10,000 MMBtu) — 767 Weighted average price differential per MMBtu $ — $ 0.42 Natural gas futures: Contract volumes (10,000 MMBtu) 250 943 Weighted average contract price per MMBtu $ 2.80 $ 3.54 Natural gas options: Contract volumes (10,000 MMBtu) 16 5 Weighted average premium received/paid $ 0.26 $ 0.06 Bunker fuel futures: Contract volumes (metric tons “MT”) — 60,500 Weighted average price per MT $ — $ 540.17 Bunker fuel swaps: Contract volumes (metric tons “MT”) — 8,500 Weighted average price per MT $ — $ 553.14 DOE diesel options: Contract volumes (1,000 Gal) — 1,950 Weighted average premium received/paid $ — $ 0.35
Schedule of Fair Value of Derivative Assets and Liabilities	The following tables reflect the estimated fair value position of our derivatives at June 30, 2024 and December 31, 2023: Unaudited Condensed Consolidated Balance Sheets Location Fair Value June 30, 2024 December 31, 2023 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Accounts receivable - trade, net $ 4,735 $ 3,710 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other (1) $ 2,718 $ 1,235 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (2,718) (1,235) 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) $ 409 $ 716 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) (409) (716) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Liability Derivatives: Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued liabilities $ (4,160) $ (5,536) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (5,326) $ (12,384) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 5,326 12,384 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (1,153) $ (120) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 1,153 120 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — (1)
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 Six Months Ended 2024 2023 2024 2023 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (59) $ 1,388 $ (2,977) $ 2,355 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Soda and sulfur services operating costs 499 (2,141) 1,387 (12,294) Total commodity derivatives $ 440 $ (753) $ (1,590) $ (9,939) Natural Gas Swap Soda and sulfur services operating costs $ (1,891) $ (7,599) $ 1,119 $ 6,486

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2024
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 June 30, 2024 and December 31, 2023. June 30, 2024 December 31, 2023 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 3,127 $ 4,735 $ — $ 1,951 $ 3,710 $ — Liabilities $ (6,479) $ (4,160) $ — $ (12,504) $ (5,536) $ —

Organization and Basis of Pre_2

Organization and Basis of Presentation and Consolidation (Details)	6 Months Ended
	Jun. 30, 2024 segment
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Number of reportable segments	4
Genesis Energy, LLC
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Ownership percentage	100%

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregated Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Disaggregation of Revenue [Line Items]
Total revenues	$ 756,261	$ 804,662	$ 1,526,366	$ 1,595,274
Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	199,325	182,699	400,182	371,504
Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	536,510	599,409	1,082,871	1,179,392
Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	20,426	22,554	43,313	44,378
Offshore Pipeline Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	99,024	91,459	201,014	182,854
Offshore Pipeline Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	99,024	91,459	201,014	182,854
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
Soda and sulfur services
Disaggregation of Revenue [Line Items]
Total revenues	389,994	462,855	790,942	907,503
Soda and sulfur services | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Soda and sulfur services | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	369,568	440,301	747,629	863,125
Soda and sulfur services | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	20,426	22,554	43,313	44,378
Marine Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	81,871	77,343	165,445	160,569
Marine Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	81,871	77,343	165,445	160,569
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
Disaggregation of Revenue [Line Items]
Total revenues	185,372	173,005	368,965	344,348
Onshore facilities and transportation | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	18,430	13,897	33,723	28,081
Onshore facilities and transportation | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	166,942	159,108	335,242	316,267
Onshore facilities and transportation | 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	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Segment Reporting Information [Line Items]
Other Assets, net of amortization	$ 1,631		$ 1,631		$ 859
Accrued Liabilities	34,378		34,378		11,460
Other Long-Term Liabilities	104,216		104,216		$ 112,734
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	756,261	$ 804,662	1,526,366	$ 1,595,274
Offshore pipeline transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	99,024	91,459	201,014	182,854
Soda and sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	389,994	462,855	790,942	907,503
Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	81,871	77,343	165,445	160,569
Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	185,372	173,005	368,965	344,348
Fee-based Revenues [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	199,325	182,699	400,182	371,504
Fee-based Revenues [Member] | Offshore pipeline transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	99,024	91,459	201,014	182,854
Fee-based Revenues [Member] | Soda and sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	0	0	0	0
Fee-based Revenues [Member] | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	81,871	77,343	165,445	160,569
Fee-based Revenues [Member] | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	18,430	13,897	33,723	28,081
Product Sales [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	536,510	599,409	1,082,871	1,179,392
Product Sales [Member] | Offshore pipeline transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	0	0	0	0
Product Sales [Member] | Soda and sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	369,568	440,301	747,629	863,125
Product Sales [Member] | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	0	0	0	0
Product Sales [Member] | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	166,942	159,108	335,242	316,267
Refinery Services [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	20,426	22,554	43,313	44,378
Refinery Services [Member] | Offshore pipeline transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	0	0	0	0
Refinery Services [Member] | Soda and sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	20,426	22,554	43,313	44,378
Refinery Services [Member] | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	0	0	0	0
Refinery Services [Member] | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues	$ 0	$ 0	$ 0	$ 0

Revenue Recognition (Revenue Ex

Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in Thousands	Jun. 30, 2024 USD ($)
Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 591,563
Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	91,299
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 70,508
Revenue expected timing of satisfaction period	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-04-01 | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 12,912
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	$ 151,333
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
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 25,853
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	$ 122,603
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
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 26,170
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	$ 77,482
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
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 13,864
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	$ 45,453
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 10,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 124,184
Revenue expected timing of satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | Onshore facilities and transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 2,500

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) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023	Dec. 31, 2022
Business Acquisition [Line Items]
Net Income Attributable to Genesis Energy, L.P.		$ 804,662		$ 1,595,274
Net Income Attributable to Common Unitholders		49,344		47,700
Net Loss Attributable to Common Unitholders, Diluted (in dollars per unit)		26,434		788
Net Loss Attributable to Common Unitholders, Basic (in dollars per unit)		$ 26,434		$ 788
Diluted (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01
Basic Net Loss per Common Unit (in dollars per unit)	$ (0.25)	0.22	$ (0.34)	0.01
Pro forma net loss per common unit, diluted (in dollars per unit)		0.22		0.01
Pro Forma net loss per common unit, basic (in dollars per unit)		$ 0.22		$ 0.01
American Natural Soda Ash Corp. (ANSAC)
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)
Deferred tax liabilities					1,482
Other long-term liabilities					(77,642)
Net Assets					$ 0
American Natural Soda Ash Corp. (ANSAC) | 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		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Revenues
Net Income Attributable to Genesis Energy, L.P.		$ 804,662		$ 1,595,274
Net Income Attributable to Common Unitholders		49,344		47,700
Net Loss Attributable to Common Unitholders, Basic (in dollars per unit)		26,434		788
Net Loss Attributable to Common Unitholders, Diluted (in dollars per unit)		$ 26,434		$ 788
As reported net income per common unit
Basic Net Loss per Common Unit (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01
Dilutive Net Loss per common unit (in dollars per unit)	$ (0.25)	0.22	$ (0.34)	0.01
Pro Forma net loss per common unit, basic (in dollars per unit)		0.22		0.01
Pro forma net loss per common unit, diluted (in dollars per unit)		$ 0.22		$ 0.01

Lease Accounting (Details)

Lease Accounting (Details) - Marine Transportation [Member] - M/T American Phoenix [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Lessor, Lease, Description [Line Items]
Operating lease income	$ 7,100	$ 5,900	$ 13,900	$ 11,700
Lease payments, remainder of 2023	14,400		14,400
Lease payments, year one	29,600		29,600
Lease payments, year two	30,700		30,700
Lease payments, year three	$ 15,200		$ 15,200

Inventories (Major Components o

Inventories (Major Components of Inventories) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Inventory Disclosure [Abstract]
Crude oil	$ 22,318	$ 22,320
Caustic soda	7,198	9,150
NaHS	12,199	17,605
Raw materials - Alkali Business	10,872	8,355
Work-in-process - Alkali Business	7,652	11,404
Finished goods, net - Alkali Business	26,684	48,706
Materials and supplies, net - Alkali Business	19,404	17,691
Total	$ 106,327	$ 135,231

Inventories (Narrative) (Detail

Inventories (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2024	Dec. 31, 2023
Inventory Disclosure [Abstract]
Inventory write-down	$ 100	$ 200

Fixed Assets, Mineral Leaseho_3

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Fixed Assets, Net) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 6,665,271	$ 6,500,897
Less: Accumulated depreciation	(2,090,138)	(1,972,596)
Net fixed assets	4,575,133	4,528,301
Settlements	(298)
Asset retirement obligation balance	248,964	243,708
Accretion expense	5,554
Crude oil and natural gas pipelines and related assets
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	2,953,262	2,945,215
Onshore facilities, machinery and equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	291,039	271,271
Onshore facilities, machinery and equipment | Alkali Business
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	1,163,200	1,147,291
Transportation equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	30,588	24,913
Marine vessels
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	1,024,287	1,021,080
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	296,424	293,733
Office equipment, furniture and fixtures
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	25,268	25,029
Construction in progress(1)
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	851,892	731,197
Other
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 29,311	$ 41,168

Fixed Assets, Mineral Leaseho_4

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Mineral Leaseholds) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Fixed Assets And Asset Retirement Obligations [Abstract]
Mineral leaseholds	$ 566,019	$ 566,019
Less: Accumulated depletion	(27,985)	(25,499)
Mineral leaseholds, net of accumulated depletion	$ 538,034	$ 540,520

Fixed Assets, Mineral Leaseho_5

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 73,341	$ 63,913	$ 143,026	$ 133,486
Depletion expense	$ 1,340	$ 1,268	$ 2,486	$ 2,149

Fixed Assets, Mineral Leaseho_6

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Asset Retirement Obligation Rollforward) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2024 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2023	$ 243,708
Accretion expense	5,554
Settlements	(298)
ARO liability balance, June 30, 2024	$ 248,964

Fixed Assets, Mineral Leaseho_7

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 248,964	$ 243,708
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 26,100

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2024	Dec. 31, 2023
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 284.2	$ 291.4

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Equity Method Investments and Joint Ventures [Abstract]
Amortization of differences attributable to Genesis’ carrying value of equity investments	$ (3,566)	$ (3,566)	$ (7,132)	$ (7,132)
Distributions received	17,092	20,678	40,341	44,512
Equity in earnings of equity investees	12,213	14,811	28,654	32,364
Genesis’ share of operating earnings	$ 15,779	$ 18,377	$ 35,786	$ 39,496

Intangible Assets (Schedule of

Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 234,946	$ 229,075
Accumulated Amortization	93,198	87,538
Carrying Value	141,748	141,537
Contract intangibles | Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	158,101	158,101
Accumulated Amortization	74,196	70,036
Carrying Value	83,905	88,065
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	76,845	70,974
Accumulated Amortization	19,002	17,502
Carrying Value	$ 57,843	$ 53,472

Intangible Assets - Schedule of

Intangible Assets - Schedule of Amortization Expense (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Goodwill and Intangible Assets Disclosure [Abstract]
Amortization of intangible assets	$ 2,826	$ 2,973	$ 5,660	$ 5,678

Intangible Assets (Schedule o_2

Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Remainder of 2021	$ 5,583		$ 5,583
2025	15,152		15,152
2026	14,840		14,840
2027	14,393		14,393
2028	14,144		14,144
Amortization of intangible assets	$ 2,826	$ 2,973	$ 5,660	$ 5,678

Debt (Schedule of Obligations U

Debt (Schedule of Obligations Under Debt Arrangements) (Details) $ in Thousands	Jun. 30, 2024 USD ($)	May 09, 2024	Dec. 31, 2023 USD ($)	Jan. 25, 2023	May 17, 2022
Debt Instrument [Line Items]
Principal	$ 4,014,590		$ 3,823,215
Unamortized Premium, Discount and Debt Issuance Costs	65,196		58,751
Net Value	3,949,394		3,764,464
5.875% Alkali senior secured notes due 2042(2)
Debt Instrument [Line Items]
Principal	400,000
Credit Facility | Revolving Credit Facility | Revolving Loan
Debt Instrument [Line Items]
Principal	134,800		298,300
Unamortized Premium, Discount and Debt Issuance Costs	0		0
Net Value	134,800		298,300
Unamortized debt issuance costs	4,300		5,700
Senior Notes | 6.250% senior unsecured notes due 2026
Debt Instrument [Line Items]
Principal	0		339,310
Unamortized Premium, Discount and Debt Issuance Costs	0		1,746
Net Value	$ 0		337,564
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	2,888		3,549
Net Value	$ 978,357		977,696
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	5,372		6,121
Net Value	$ 673,988		673,239
Interest rate	7.75%
Senior Notes | 5.875% Alkali senior secured notes due 2042(2)
Debt Instrument [Line Items]
Principal	$ 419,185		425,000
Unamortized Premium, Discount and Debt Issuance Costs	21,395		21,791
Net Value	$ 397,790		403,209
Interest rate	5.875%
Interest rate, limited term percentage					10
Senior Notes | 8.250% Senior Unsecured Notes Due 2029
Debt Instrument [Line Items]
Principal	$ 600,000		600,000
Unamortized Premium, Discount and Debt Issuance Costs	15,610		17,202
Net Value	$ 584,390		582,798
Interest rate	8.25%
2030 Notes | Senior Notes
Debt Instrument [Line Items]
Principal	$ 500,000		500,000
Unamortized Premium, Discount and Debt Issuance Costs	7,678		8,342
Net Value	$ 492,322		491,658
Interest rate	8.875%			8.875%
2032 Notes | Senior Notes
Debt Instrument [Line Items]
Principal	$ 700,000		0
Unamortized Premium, Discount and Debt Issuance Costs	12,253		0
Net Value	$ 687,747		$ 0
Interest rate	7.875%	7.875%

Debt (Narrative) (Details)

Debt (Narrative) (Details)						3 Months Ended		6 Months Ended
	Jun. 30, 2024 USD ($)	May 09, 2024 USD ($)	Feb. 17, 2023 USD ($) extension	Jan. 26, 2023 USD ($)	Jan. 25, 2023 USD ($)	Jun. 30, 2024 USD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2024 USD ($)	Jun. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)	May 17, 2022
Debt Instrument [Line Items]
Repayment of Alkali senior secured notes (Note 10)								$ 5,815,000	$ 0
Restricted cash	$ 18,804,000					$ 18,804,000		18,804,000		$ 18,804,000
Repayment of senior unsecured notes								339,310,000	341,135,000
Proceeds from issuance of debt					$ 491,000,000
Loss on extinguishment of debt						(1,429,000)	$ (3,000)	1,429,000	$ 1,812,000
SENIOR UNSECURED NOTES, net of debt issuance costs, discount and premium	$ 3,500,000,000					$ 3,500,000,000		$ 3,500,000,000		3,100,000,000
Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Credit facility extension period			1 year
Credit facility, number of extensions | extension			2
5.875% Alkali senior secured notes due 2042(2) | Senior Notes
Debt Instrument [Line Items]
Interest rate	5.875%					5.875%		5.875%
Repayment of Alkali senior secured notes (Note 10)						$ 2,800,000		$ 5,800,000
Year five	$ 71,900,000					71,900,000		71,900,000
Accrued Liabilities	12,300,000					12,300,000		12,300,000		11,600,000
Restricted cash	$ 18,800,000					$ 18,800,000		$ 18,800,000
Proceeds from issuance of debt, net		$ 688,000,000
Interest rate, limited term percentage											10
Senior Notes | 2032 Notes
Debt Instrument [Line Items]
Interest rate	7.875%	7.875%				7.875%		7.875%
Face amount		$ 700,000,000
Senior Notes | 2030 Notes
Debt Instrument [Line Items]
Interest rate	8.875%				8.875%	8.875%		8.875%
Face amount					$ 500,000,000
Senior Notes | 5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Interest rate					5.625%
Repayments of long term debt				$ 24,800,000	$ 316,300,000
Loss on extinguishment of debt					$ 1,800,000
6.250% senior unsecured notes due 2026 | Senior Notes
Debt Instrument [Line Items]
Interest rate	6.25%					6.25%		6.25%
Repayment of senior unsecured notes		339,300,000
Issuance cost, writeoff		$ 1,400,000
Revolving Credit Facility | Revolving Loan | Credit Facility
Debt Instrument [Line Items]
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	134,800,000					134,800,000		134,800,000
Letters of credit, outstanding amount	4,500,000					4,500,000		4,500,000
Remaining borrowing capacity	710,700,000					710,700,000		710,700,000
Unamortized debt issuance costs	4,300,000					4,300,000		4,300,000		$ 5,700,000
Maximum borrowing capacity			$ 850,000,000
Revolving Credit Facility | Revolving Loan | Credit Facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount borrowed	$ 17,200,000					17,200,000		$ 17,200,000
Revolving Credit Facility | Revolving Loan | Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	3%
Revolving Credit Facility | Revolving Loan | Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2%
Revolving Credit Facility | Revolving Loan | Credit Facility | Federal Funds Effective Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								0.50%
Revolving Credit Facility | Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage	3%
Minimum | Revolving Credit Facility | Revolving Loan | Credit Facility
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage								0.30%
Minimum | Revolving Credit Facility | Revolving Loan | Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								2.25%
Minimum | Revolving Credit Facility | Revolving Loan | Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								1.25%
Minimum | Revolving Credit Facility | Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage								2.25%
Maximum | Revolving Credit Facility | Revolving Loan | Credit Facility
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
Maximum | Revolving Credit Facility | Revolving Loan | Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								3.50%
Maximum | Revolving Credit Facility | Revolving Loan | Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | One-month Tenor
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								1%
Maximum | Revolving Credit Facility | Revolving Loan | Credit Facility | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Term SOFR Adjustment
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								0.10%
Maximum | Revolving Credit Facility | Revolving Loan | Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate								2.50%
Maximum | Revolving Credit Facility | Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage								3.50%
Guarantor Subsidiary | Genesis Energy, LLC | Genesis Finance Corporation | Senior Notes
Obligation with Joint and Several Liability Arrangement [Line Items]
Percentage of equity interest								100%

Partners' Capital, Mezzanine _3

Partners' Capital, Mezzanine Capital and Distributions (Common Cash Distributions Paid) (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2024	May 15, 2024	Feb. 14, 2024	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023	Apr. 03, 2023
Class A Convertible Preferred Stock Units
Partners Capital And Distributions [Line Items]
Class A Convertible Preferred Units redeemed, value (dollars)							$ 1,100
Common Unitholders
Partners Capital And Distributions [Line Items]
Date Paid		May 15, 2024	Feb. 14, 2024	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023
Per Unit Amount (in dollars per unit)		$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15
Total Amount		$ 18,370	$ 18,370	$ 18,370	$ 18,387	$ 18,387
Common Unitholders | Subsequent Event
Partners Capital And Distributions [Line Items]
Date Paid	Aug. 14, 2024
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) $ / shares in Units, $ in Thousands			3 Months Ended		6 Months Ended		12 Months Ended	31 Months Ended
	Apr. 03, 2023 USD ($) $ / shares shares	Sep. 23, 2019	Jun. 30, 2024 USD ($) shares	Jun. 30, 2023 USD ($)	Jun. 30, 2024 USD ($) shares	Jun. 30, 2023 USD ($)	Dec. 31, 2023 USD ($) $ / shares shares	Jun. 30, 2024 shares	Aug. 08, 2023 shares
Partners Capital And Distributions [Line Items]
Common units outstanding (in units)			122,464,318		122,464,318		122,464,318	122,464,318
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units | $			$ (21,894)	$ (22,910)	$ (43,788)	$ (46,912)
Proceeds from Noncontrolling Interests | $					$ 16,200	34,920
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%			80%
Subsidiary | Alkali Holdings
Partners Capital And Distributions [Line Items]
Period for occurrence of triggering events		6 years 6 months
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)									12,253,922
Stock repurchased and cancelled (in shares)							114,900
Shares purchased (in shares) | $ / shares							$ 9.09
Purchase price | $							$ 1,000
Class A Convertible Preferred Stock Units
Partners Capital And Distributions [Line Items]
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units | $			$ (21,900)	$ (24,000)	$ (43,800)	$ (48,000)
Class A Convertible Preferred Units redeemed (in shares)	741,620
Class A Convertible Preferred units redeemed (in dollars per share) | $ / shares	$ 33.71
Class A Convertible Preferred Units, carrying value (dollars per share) | $ / shares	$ 35.2
Class A Convertible Preferred Units redeemed, value (dollars) | $	$ 1,100
Temporary equity, adjustment | $	$ 1,100
Limited Partner [Member] | Class A Common Units
Partners Capital And Distributions [Line Items]
Common units outstanding (in units)			122,424,321		122,424,321			122,424,321
Limited Partner [Member] | Class B Common Units
Partners Capital And Distributions [Line Items]
Common units outstanding (in units)			39,997		39,997			39,997
Limited Partner [Member] | Preferred Class A
Partners Capital And Distributions [Line Items]
Common units outstanding (in units)			23,111,918		23,111,918			23,111,918

Partners' Capital, Mezzanine _5

Partners' Capital, Mezzanine Capital and Distributions (Preferred Cash Distributions Paid) (Details) - USD ($)	Aug. 14, 2024	May 15, 2024	Feb. 14, 2024	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023	Apr. 03, 2023
Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Class A Convertible Preferred Units, carrying value (dollars per share)							$ 35.2
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	$ 0.9473	$ 0.9473
Total Amount		$ 21,894,000	$ 21,894,000	$ 22,612,000	$ 23,314,000	$ 24,002,000
Preferred Unitholders | Class A Convertible Preferred Stock Units | Subsequent Event
Temporary Equity [Line Items]
Per Unit Amount (in dollars per unit)	$ 0.9473
Total Amount	$ 21,894,000
Common Unitholders
Temporary Equity [Line Items]
Date Paid		May 15, 2024	Feb. 14, 2024	Nov. 14, 2023	Aug. 14, 2023	May 15, 2023
Per Unit Amount (in dollars per unit)		$ 0.15	$ 0.15	$ 0.15	$ 0.15	$ 0.15
Total Amount		$ 18,370,000	$ 18,370,000	$ 18,370,000	$ 18,387,000	$ 18,387,000
Common Unitholders | Subsequent Event
Temporary Equity [Line Items]
Date Paid	Aug. 14, 2024
Per Unit Amount (in dollars per unit)	$ 0.15
Total Amount	$ 18,370,000

Net Loss Per Common Unit (Detai

Net Loss Per Common Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Net Income per Common Unit [Abstract]
Net income (loss) attributable to Genesis Energy, L.P.	$ (8,744)	$ 49,344	$ 2,609	$ 47,700
Less: Accumulated distributions and returns attributable to Class A Convertible Preferred Units	(21,894)	(22,910)	(43,788)	(46,912)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(30,638)	26,434	(41,179)	788
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (30,638)	$ 26,434	$ (41,179)	$ 788
Dilutive Weighted Average Outstanding Units (in units)	122,464	122,579	122,464	122,579
Basic Net Loss per Common Unit (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01
Dilutive Net Loss per common unit (in dollars per unit)	$ (0.25)	$ 0.22	$ (0.34)	$ 0.01

Business Segment Information (N

Business Segment Information (Narrative) (Details)	6 Months Ended
	Jun. 30, 2024 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		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Segment Reporting Information [Line Items]
Total Segment Margin	$ 168,313	$ 214,618	$ 349,411	$ 409,747
Revenues	756,261	804,662	1,526,366	1,595,274
Offshore pipeline transportation
Segment Reporting Information [Line Items]
Revenues	99,024	91,459	201,014	182,854
Soda and sulfur services
Segment Reporting Information [Line Items]
Revenues	389,994	462,855	790,942	907,503
Onshore facilities and transportation
Segment Reporting Information [Line Items]
Revenues	185,372	173,005	368,965	344,348
Marine transportation
Segment Reporting Information [Line Items]
Revenues	81,871	77,343	165,445	160,569
Operating Segments
Segment Reporting Information [Line Items]
Total Segment Margin	168,313	214,618	349,411	409,747
Capital expenditures	110,118	131,345	211,175	214,370
Revenues	756,261	804,662	1,526,366	1,595,274
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total Segment Margin	86,131	93,300	183,937	191,238
Capital expenditures	55,788	91,645	119,414	143,698
Revenues	99,024	91,459	201,014	182,854
Operating Segments | Soda and sulfur services
Segment Reporting Information [Line Items]
Total Segment Margin	41,611	89,255	86,993	155,362
Capital expenditures	18,106	26,622	36,706	46,607
Revenues	392,226	465,077	795,179	911,983
Operating Segments | Onshore facilities and transportation
Segment Reporting Information [Line Items]
Total Segment Margin	9,028	6,305	15,575	11,695
Capital expenditures	6,692	2,088	13,213	4,018
Revenues	183,140	170,783	364,728	339,868
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total Segment Margin	31,543	25,758	62,906	51,452
Capital expenditures	29,532	10,990	41,842	20,047
Revenues	81,871	77,343	165,445	160,569
Intersegment
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Intersegment | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Intersegment | Soda and sulfur services
Segment Reporting Information [Line Items]
Revenues	(2,232)	(2,222)	(4,237)	(4,480)
Intersegment | Onshore facilities and transportation
Segment Reporting Information [Line Items]
Revenues	2,232	2,222	4,237	4,480
Intersegment | Marine transportation
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 0	$ 0

Business Segment Information _2

Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Segment Reporting Information [Line Items]
Total consolidated assets	$ 6,951,302	$ 7,018,778
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total consolidated assets	2,653,561	2,580,032
Operating Segments | Soda and sulfur services
Segment Reporting Information [Line Items]
Total consolidated assets	2,616,451	2,705,350
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total consolidated assets	639,386	645,020
Operating Segments | Onshore facilities and transportation
Segment Reporting Information [Line Items]
Total consolidated assets	965,850	1,019,113
Other assets
Segment Reporting Information [Line Items]
Total consolidated assets	$ 76,054	$ 69,263

Business Segment Information (R

Business Segment Information (Reconciliation of Segment Margin to (Loss) Income from Continuing Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income (loss) attributable to Genesis Energy, L.P.	$ (8,744)	$ 49,344	$ 2,609	$ 47,700
Corporate general and administrative expenses	20,007	18,487	36,056	34,251
Depreciation, depletion, amortization and accretion	80,386	71,754	(156,929)	(147,689)
Interest expense, net	70,870	61,623	139,604	122,477
Adjustment to include distributable cash generated by equity investees not included in income and exclude equity in investees net income(1)	4,879	5,867	(11,687)	(12,148)
Unrealized losses (gains) on derivative transactions excluding fair value hedges, net of changes in inventory value	(5,860)	2,888	(10,941)	30,020
Other non-cash items	(2,496)	(7,197)	4,685	9,658
Loss on extinguishment of debt	(1,429)	(3)	1,429	1,812
Differences in timing of cash receipts for certain contractual arrangements(3)	7,820	11,559	15,892	22,134
Income tax expense	22	290	831	1,174
Total Segment Margin	$ 168,313	$ 214,618	349,411	409,747
Unrealized (losses) gains from valuation of embedded derivatives			$ 10,941	$ (30,021)
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%

Transactions with Related Par_3

Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Dec. 31, 2023
Related Party Transaction [Line Items]
Revenues	$ 756,261	$ 804,662	$ 1,526,366	$ 1,595,274
Poseidon
Related Party Transaction [Line Items]
Equity method investment, ownership percentage	64%		64%
CEO
Related Party Transaction [Line Items]
Cost and expenses	$ 165	165	$ 330	330
Equity Method Investee
Related Party Transaction [Line Items]
Revenues	6,025	5,454	11,008	9,046
Cost and expenses	298	1,755	584	2,037
Other receivables	2,900		2,900		$ 1,900
Equity Method Investee | Fees
Related Party Transaction [Line Items]
Revenues	$ 2,600	$ 2,500	$ 5,200	$ 5,000

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
(Increase) decrease in:
Accounts receivable	$ 73,043	$ 147,999
Inventories	40,761	(20,187)
Deferred charges	6,497	21,076
Other current assets	10,696	(129)
Increase (decrease) in:
Accounts payable	(68,308)	(130,131)
Accrued liabilities	(13,457)	(17,671)
Net changes in components of operating assets and liabilities	$ 49,232	$ 957

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 126	$ 117.5
Interest paid, capitalized	23.3	18.3
Incurred liabilities for fixed and intangible asset additions	$ 43.2	$ 64

Derivatives (Schedule of Outsta

Derivatives (Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments) (Details) - 6 months ended Jun. 30, 2024 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)	249
Weighted average contract price | $ / bbl		78.32
Designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	0
Weighted average contract price | $ / bbl		0
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls)	32
Weighted average contract price | $ / bbl		80.72
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (bbls)	16
Contract volume (MMBTU) | MMBTU			250
Weighted average contract price		0.26		2.80
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 | Swaps | 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 | 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)	53
Weighted average contract price | $ / bbl		79.66
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (bbls)	5
Contract volume (MMBTU) | MMBTU			943
Weighted average contract price		0.06		3.54
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (MT) | T					60,500
Weighted average contract price (MT) | $ / T						540.17
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swaps | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU			767
Weighted average contract price | $ / MMBTU				0.42
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swaps | Fuel Oil
Derivative [Line Items]
Contract volumes (MT) | T					8,500
Weighted average contract price (MT) | $ / T						553.14
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							1,950
Weighted average contract price | $ / gal								0.35

Derivatives (Schedule of Fair V

Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Dec. 31, 2023
Derivatives, Fair Value [Line Items]
SENIOR UNSECURED NOTES, net of debt issuance costs, discount and premium	$ 3,500,000	$ 3,100,000
Not qualifying or not designated as hedges under accounting rules | Commodity Derivatives
Derivatives, Fair Value [Line Items]
Asset Derivatives	0	0
Liability Derivatives	0	0
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	2,718	1,235
Derivative Asset, Fair Value, Gross Liability	(2,718)	(1,235)
Derivative Liability, Fair Value, Gross Liability	(5,326)	(12,384)
Derivative Liability, Fair Value, Gross Asset	5,326	12,384
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	4,735	3,710
Not qualifying or not designated as hedges under accounting rules | Swaps | Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(4,160)	(5,536)
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	409	716
Derivative Asset, Fair Value, Gross Liability	(409)	(716)
Derivative Liability, Fair Value, Gross Liability	(1,153)	(120)
Derivative Liability, Fair Value, Gross Asset	$ 1,153	$ 120

Derivatives (Narrative) (Detail

Derivatives (Narrative) (Details) - USD ($)			3 Months Ended		6 Months Ended		9 Months Ended
	Jan. 26, 2023	Jan. 25, 2023	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Sep. 30, 2023	May 09, 2024	Dec. 31, 2023
Derivatives, Fair Value [Line Items]
Net broker receivable			$ 13,000,000		$ 13,000,000				$ 10,900,000
Initial margin			4,300,000		4,300,000				5,700,000
Variation margin					8,700,000		$ 5,200,000
Proceeds from issuance of debt		$ 491,000,000
Restricted cash			18,804,000		18,804,000				18,804,000
Loss on extinguishment of debt			(1,429,000)	$ (3,000)	1,429,000	$ 1,812,000
SENIOR UNSECURED NOTES, net of debt issuance costs, discount and premium			$ 3,500,000,000		$ 3,500,000,000				$ 3,100,000,000
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
Interest rate		5.625%
Loss on extinguishment of debt		$ 1,800,000
Senior Notes | 2032 Notes
Derivatives, Fair Value [Line Items]
Interest rate			7.875%		7.875%			7.875%
Face amount								$ 700,000,000
Senior Notes | 2030 Notes
Derivatives, Fair Value [Line Items]
Interest rate		8.875%	8.875%		8.875%
Face amount		$ 500,000,000

Derivatives (Schedule of Effect

Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Commodity derivatives - futures and call options
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ 440	$ (753)	$ (1,590)	$ (9,939)
Natural Gas Swap | Soda and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(1,891)		1,119
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	(59)	1,388	(2,977)	2,355
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	$ 499	(2,141)	$ 1,387	(12,294)
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		$ (7,599)		$ 6,486

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	Jun. 30, 2024	Dec. 31, 2023
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 3,127	$ 1,951
Liabilities Fair Value	(6,479)	(12,504)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	4,735	3,710
Liabilities Fair Value	(4,160)	(5,536)
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	Jun. 30, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying value of senior unsecured notes	$ 3,500,000	$ 3,100,000
Fair value of senior unsecured notes	3,500,000	3,200,000
Principal	4,014,590	$ 3,823,215
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

Subsequent Events (Details)

Subsequent Events (Details)	Jul. 19, 2024 USD ($) extension	Jun. 30, 2024 USD ($)	Dec. 31, 2023 USD ($)	Feb. 17, 2023 USD ($)
Subsequent Event [Line Items]
Net Value		$ 3,949,394,000	$ 3,764,464,000
8.000% senior unsecured notes due 2027 | Senior Notes
Subsequent Event [Line Items]
Net Value		$ 978,357,000	977,696,000
Interest rate		8%
7.750% senior unsecured notes due 2028 | Senior Notes
Subsequent Event [Line Items]
Net Value		$ 673,988,000	673,239,000
Interest rate		7.75%
Revolving Credit Facility | Revolving Loan | Credit Facility
Subsequent Event [Line Items]
Maximum borrowing capacity				$ 850,000,000
Net Value		$ 134,800,000	$ 298,300,000
Subsequent Event | Revolving Loan | Credit Facility
Subsequent Event [Line Items]
Credit facility extension period	1 year
Credit facility, number of extensions | extension	2
Subsequent Event | 8.000% senior unsecured notes due 2027 | Senior Notes
Subsequent Event [Line Items]
Net Value	$ 150,000,000
Interest rate	8%
Subsequent Event | 7.750% senior unsecured notes due 2028 | Senior Notes
Subsequent Event [Line Items]
Net Value	$ 150,000,000
Interest rate	7.75%
Subsequent Event | Revolving Credit Facility | Revolving Loan | Credit Facility
Subsequent Event [Line Items]
Maximum borrowing capacity	$ 900,000,000

Uncategorized Items - gel-20240

Label	Element	Value
Payments for (Proceeds from) Other Investing Activities	us-gaap_PaymentsForProceedsFromOtherInvestingActivities	$ (4,332,000)