Genesis Energy (GEL) 10-Q 4 May 22 2022 Q1 Quarterly report Financial data

Cover

Cover - shares	3 Months Ended
	Mar. 31, 2022	May 02, 2022
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	1-12295
Entity Registrant Name	GENESIS ENERGY LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	76-0513049
Entity Address, Address Line One	919 Milam, Suite 2100,
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	(713)
Local Phone Number	860-2500
Title of 12(b) Security	Common units
Trading Symbol	GEL
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001022321
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Amendment Flag	false
Class A Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		122,539,221
Class B Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		39,997

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
CURRENT ASSETS:
Cash and cash equivalents	$ 9,547	$ 19,987
Restricted cash	5,005	5,005
Accounts receivable - trade, net	531,791	400,334
Inventories	84,094	77,958
Other	39,162	39,200
Total current assets	669,599	542,484
FIXED ASSETS, at cost	5,519,055	5,464,040
Less: Accumulated depreciation	(1,607,285)	(1,551,855)
Net fixed assets	3,911,770	3,912,185
MINERAL LEASEHOLDS, net of accumulated depletion	547,985	549,005
EQUITY INVESTEES	290,005	294,050
INTANGIBLE ASSETS, net of amortization	126,783	127,063
GOODWILL	301,959	301,959
RIGHT OF USE ASSETS, net	136,386	140,796
OTHER ASSETS, net of amortization	34,712	38,259
TOTAL ASSETS	6,019,199	5,905,801
CURRENT LIABILITIES:
Accounts payable - trade	365,935	264,316
Accrued liabilities	231,270	232,623
Total current liabilities	597,205	496,939
SENIOR SECURED CREDIT FACILITY	94,800	49,000
SENIOR UNSECURED NOTES, net of debt issuance costs	2,932,003	2,930,505
DEFERRED TAX LIABILITIES	14,476	14,297
OTHER LONG-TERM LIABILITIES	437,609	434,925
Total liabilities	4,076,093	3,925,666
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at March 31, 2022 and December 31, 2021	790,115	790,115
Redeemable noncontrolling interests, 250,114 and 246,394 preferred units issued and outstanding at March 31, 2022 and December 31, 2021, respectively	267,242	259,568
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at March 31, 2022 and December 31, 2021	597,783	641,313
Accumulated other comprehensive loss	(5,485)	(5,607)
Noncontrolling interests	293,451	294,746
Total partners’ capital	885,749	930,452
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ 6,019,199	$ 5,905,801

UNAUDITED CONDENSED CONSOLIDA_2

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Mar. 31, 2022	Dec. 31, 2021
Common units issued (in units)	122,579,218	122,579,218
Common units outstanding (in units)	122,579,218	122,579,218
Class A Convertible Preferred Stock Units
Number preferred units issued (in units)	25,336,778	25,336,778
Number of preferred units outstanding (in units)	25,336,778	25,336,778
Redeemable Noncontrolling Interest Preferred Units
Number preferred units issued (in units)	250,114	246,394
Number of preferred units outstanding (in units)	250,114	246,394

UNAUDITED CONDENSED CONSOLIDA_3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
REVENUES:
Total revenues	$ 631,947	$ 521,219
COSTS AND EXPENSES:
General and administrative	15,122	11,666
Depreciation, depletion and amortization	69,506	66,286
Total costs and expenses	580,276	493,198
OPERATING INCOME	51,671	28,021
Equity in earnings of equity investees	12,444	20,660
Interest expense	(55,104)	(57,829)
Other expense	(4,258)	(20,065)
Income (loss) from operations before income taxes	4,753	(29,213)
Income tax expense	(304)	(222)
NET INCOME (LOSS)	4,449	(29,435)
Net loss (income) attributable to noncontrolling interests	(1,876)	2
Net income attributable to redeemable noncontrolling interests	(7,823)	(4,791)
NET LOSS ATTRIBUTABLE TO GENESIS ENERGY, L.P.	(5,250)	(34,224)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)	(18,684)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(23,934)	(52,908)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (23,934)	$ (52,908)
NET LOSS PER COMMON UNIT (Note 11):
Basic (in dollars per unit)	$ (0.20)	$ (0.43)
Diluted (in dollars per unit)	$ (0.20)	$ (0.43)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic (in units)	122,579	122,579
Diluted (in units)	122,579	122,579
Offshore pipeline transportation
REVENUES:
Total revenues	$ 68,068	$ 64,384
COSTS AND EXPENSES:
Cost of products and services sold	23,016	20,716
Sodium minerals and sulfur services
REVENUES:
Total revenues	285,674	227,287
COSTS AND EXPENSES:
Cost of products and services sold	213,625	184,431
Marine transportation
REVENUES:
Total revenues	55,774	40,331
COSTS AND EXPENSES:
Cost of products and services sold	43,728	33,086
Onshore facilities and transportation
REVENUES:
Total revenues	222,431	189,217
Onshore facilities and transportation | Onshore facilities and transportation product costs
COSTS AND EXPENSES:
Cost of products and services sold	199,602	160,751
Onshore facilities and transportation | Onshore facilities and transportation operating costs
COSTS AND EXPENSES:
Cost of products and services sold	$ 15,677	$ 16,262

UNAUDITED CONDENSED CONSOLIDA_4

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Net loss	$ 4,449	$ (29,435)
Other comprehensive income:
Decrease in benefit plan liability	122	122
Total Comprehensive income (loss)	4,571	(29,313)
Comprehensive loss (income) attributable to noncontrolling interests	(1,876)	2
Comprehensive income attributable to redeemable noncontrolling interests	(7,823)	(4,791)
Comprehensive loss attributable to Genesis Energy, L.P.	$ (5,128)	$ (34,102)

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, 2020			122,579
Partners' capital, beginning balance at Dec. 31, 2020	$ 818,848	$ 829,326		$ (1,113)	$ (9,365)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(34,226)	(34,224)		(2)
Cash distributions to partners	(18,387)	(18,387)
Cash contributions from noncontrolling interests	236			236
Other comprehensive income	122				122
Distributions to Class A Convertible Preferred unitholders	(18,684)	(18,684)
Partners' capital, ending balance (in shares) at Mar. 31, 2021			122,579
Partners' capital, ending balance at Mar. 31, 2021	747,909	758,031		(879)	(9,243)
Partners' capital, beginning balance (in shares) at Dec. 31, 2021			122,579
Partners' capital, beginning balance at Dec. 31, 2021	930,452	641,313		294,746	(5,607)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	(3,374)	(5,250)		1,876
Cash distributions to partners	(18,387)	(18,387)
Adjustment to valuation of noncontrolling interest in subsidiary	0	(1,209)		1,209
Cash distributions to noncontrolling interests	(5,202)			(5,202)
Cash contributions from noncontrolling interests	822			822
Other comprehensive income	122				122
Distributions to Class A Convertible Preferred unitholders	(18,684)	(18,684)
Partners' capital, ending balance (in shares) at Mar. 31, 2022			122,579
Partners' capital, ending balance at Mar. 31, 2022	$ 885,749	$ 597,783		$ 293,451	$ (5,485)

UNAUDITED CONDENSED CONSOLIDA_6

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ 4,449	$ (29,435)
Adjustments to reconcile net income (loss) to net cash provided by operating activities -
Depreciation, depletion and amortization	69,506	66,286
Amortization and write-off of debt issuance costs and premium	2,034	3,210
Payments received under previously owned direct financing leases	0	17,500
Equity in earnings of investments in equity investees	(12,444)	(20,660)
Cash distributions of earnings of equity investees	12,846	19,929
Non-cash effect of long-term incentive compensation plans	3,061	1,560
Deferred and other tax liabilities	179	72
Unrealized losses (gains) on derivative transactions	(1,903)	17,599
Other, net	5,686	6,160
Net changes in components of operating assets and liabilities (Note 14)	(29,169)	(5,062)
Net cash provided by operating activities	54,245	77,159
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(80,199)	(39,388)
Cash distributions received from equity investees - return of investment	6,008	9,314
Investments in equity investees	(1,323)	0
Proceeds from asset sales	0	23
Net cash used in investing activities	(75,514)	(30,051)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	181,700	212,000
Repayments on senior secured credit facility	(135,900)	(156,700)
Net proceeds from issuance of preferred units (Note 10)	0	17,738
Repayment of senior unsecured notes (Note 9)	0	(80,859)
Debt issuance costs	0	(1,916)
Contributions from noncontrolling interests	822	236
Distributions to noncontrolling interests	(5,202)	0
Distributions to common unitholders	(18,387)	(18,387)
Distributions to preferred unitholders	(18,684)	(18,684)
Other, net	6,480	6,233
Net cash provided by (used in) financing activities	10,829	(40,339)
Net increase (decrease) in cash and cash equivalents and restricted cash	(10,440)	6,769
Cash and cash equivalents and restricted cash at beginning of period	24,992	27,018
Cash and cash equivalents and restricted cash at end of period	$ 14,552	$ 33,787

Organization and Basis of Prese

Organization and Basis of Presentation and Consolidation	3 Months Ended
	Mar. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation and Consolidation	Organization and Basis of Presentation and Consolidation Organization We are a growth-oriented master limited partnership founded in Delaware in 1996 and focused on the midstream segment of the crude oil and natural gas industry as well as the production of natural soda ash. Our operations are primarily located in the Gulf Coast region of the United States, Wyoming and in the Gulf of Mexico. We provide an integrated suite of services to refiners, crude oil and natural gas producers and industrial and commercial enterprises and have a diverse portfolio of assets, including pipelines, offshore hub and junction platforms, our trona and trona-based exploring, mining, processing, producing, marketing and selling business based in Wyoming (our “Alkali Business”), refinery-related plants, storage tanks and terminals, railcars, rail unloading facilities, barges and other vessels and trucks. We are owned 100% by our limited partners. Genesis Energy, LLC, our general partner, is a wholly-owned subsidiary. Our general partner has sole responsibility for conducting our business and managing our operations. We conduct our operations and own our operating assets through our subsidiaries and joint ventures. We currently manage our businesses through the following four divisions that constitute our reportable segments: • Offshore pipeline transportation, which includes processing of crude oil and natural gas in the Gulf of Mexico; • Sodium minerals and sulfur services involving trona and trona-based exploring, mining, processing, marketing and selling activities, as well as soda ash production and processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and selling the related by-product, sodium hydrosulfide (or “NaHS,” commonly pronounced “nash”); • Onshore facilities and transportation, which include terminaling, blending, storing, marketing and transporting crude oil and petroleum products; and • Marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America Basis of Presentation and Consolidation The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including our general partner, Genesis Energy, LLC. Our results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the fiscal year. The Unaudited Condensed Consolidated Financial Statements included herein have been prepared by us without audit pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Accordingly, they reflect all adjustments (which consist solely of normal recurring adjustments) that are, in the opinion of management, necessary for a fair presentation of the financial results for interim periods. Certain information and notes normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to such rules and regulations. However, we believe that the disclosures are adequate to make the information presented not misleading when read in conjunction with the information contained in the periodic reports we file with the SEC pursuant to the Securities Exchange Act of 1934, including the Consolidated Financial Statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2021 (our “Annual Report”). Except per unit amounts, or as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars.

Recent Accounting Developments

Recent Accounting Developments	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting Developments Recent and Proposed Accounting Pronouncements In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848), which provides expedients and exceptions for accounting treatment of contracts which are affected by the anticipated discontinuation of the London InterBank Offered Rate (“LIBOR”) and other rates resulting from rate reform that are entered into on or before December 31, 2022. Contract terms that are modified due to the replacement of a reference rate are not required to be remeasured or reassessed under relevant accounting standards. The discontinuation of LIBOR is expected to occur in 2023. We are evaluating the provisions of ASU 2020-04 and have not yet determined the impact on our Consolidated Financial Statements and disclosures related to our senior secured credit facility due to the uncertain timing of the transition to another interest rate benchmark.

Revenue Recognition

Revenue Recognition	3 Months Ended
	Mar. 31, 2022
Revenue Recognition [Abstract]
Revenue Recognition	Revenue Recognition Revenue from Contracts with Customers The following tables reflect the disaggregation of our revenues by major category for the three months ended March 31, 2022 and 2021, respectively: Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 68,068 $ — $ 55,774 $ 13,631 $ 137,473 Product Sales — 258,775 — 208,800 467,575 Refinery Services — 26,899 — — 26,899 $ 68,068 $ 285,674 $ 55,774 $ 222,431 $ 631,947 Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 64,384 $ — $ 40,331 $ 24,394 $ 129,109 Product Sales — 204,778 — 164,823 369,601 Refinery Services — 22,509 — — 22,509 $ 64,384 $ 227,287 $ 40,331 $ 189,217 $ 521,219 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, 2021 and March 31, 2022: Contract Assets Contract Liabilities Current Assets- Other Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2021 $ 13,563 $ 2,619 $ 19,028 Balance at March 31, 2022 4,687 2,415 18,498 Transaction Price Allocations to Remaining Performance Obligations We are required to disclose the amount of our transaction prices that are allocated to unsatisfied performance obligations as of March 31, 2022. We are exempt from disclosing performance obligations with a duration of one year or less, revenue recognized related to performance obligations where the consideration corresponds directly with the value provided to customers and contracts with variable consideration that is allocated wholly to an unsatisfied performance obligation or promise to transfer a good or service that is part of a series in accordance with ASC 606. The majority of our contracts qualify for one of these expedients or exemptions. For the remaining contract types that involve revenue recognition over a long-term period with long-term fixed consideration (adjusted for indexing as required), we determined our allocations of transaction price that relate to unsatisfied performance obligations. For our tiered pricing offshore transportation contracts, we provide firm capacity for both fixed and variable consideration over a long term period. Therefore, we have allocated the remaining contract value to future periods. The following chart depicts how we expect to recognize revenues for future periods related to these contracts: Offshore Pipeline Transportation Onshore Facilities and Transportation Remainder of 2022 $ 55,635 $ 5,400 2023 65,645 7,200 2024 59,034 1,800 2025 62,699 — 2026 44,691 — Thereafter 57,612 — Total $ 345,316 $ 14,400

Lease Accounting

Lease Accounting	3 Months Ended
	Mar. 31, 2022
Leases [Abstract]
Lease Accounting	Lease Accounting Lessee Arrangements We lease a variety of transportation equipment (primarily railcars), terminals, land and facilities, and office space and equipment. Lease terms vary and can range from short term (under 12 months) to long term (greater than 12 months). A majority of our leases contain options to extend the life of the lease at our sole discretion. We considered these options when determining the lease terms used to derive our right of use assets and associated lease liabilities. Leases with a term of less than 12 months are not recorded on our Unaudited Condensed Consolidated Balance Sheets and we recognize lease expense for these leases on a straight-line basis over the lease term. Our “Right of Use Assets, net” balance includes our unamortized initial direct costs associated with certain of our transportation equipment leases. Additionally, it includes our unamortized prepaid rents, our deferred rents, and our previously classified intangible asset associated with a favorable lease. Our lease liability includes our cease-use provision for railcars no longer in use. Our short-term and long-term lease liabilities are recorded within “Accrued liabilities” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets. Lessor Arrangements We have the following contracts in which we act as a lessor. We also, from time to time, sublease certain of our transportation and facilities equipment to third parties. Operating Leases During the three months ended March 31, 2022 and 2021, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, which is included in our marine transportation segment. Our lease revenues for this arrangement (inclusive of fixed and variable consideration) were $4.1 million and $3.4 million for the three months ended March 31, 2022 and 2021, respectively.
Lease Accounting	Lease Accounting Lessee Arrangements We lease a variety of transportation equipment (primarily railcars), terminals, land and facilities, and office space and equipment. Lease terms vary and can range from short term (under 12 months) to long term (greater than 12 months). A majority of our leases contain options to extend the life of the lease at our sole discretion. We considered these options when determining the lease terms used to derive our right of use assets and associated lease liabilities. Leases with a term of less than 12 months are not recorded on our Unaudited Condensed Consolidated Balance Sheets and we recognize lease expense for these leases on a straight-line basis over the lease term. Our “Right of Use Assets, net” balance includes our unamortized initial direct costs associated with certain of our transportation equipment leases. Additionally, it includes our unamortized prepaid rents, our deferred rents, and our previously classified intangible asset associated with a favorable lease. Our lease liability includes our cease-use provision for railcars no longer in use. Our short-term and long-term lease liabilities are recorded within “Accrued liabilities” and “Other long-term liabilities,” respectively, on our Unaudited Condensed Consolidated Balance Sheets. Lessor Arrangements We have the following contracts in which we act as a lessor. We also, from time to time, sublease certain of our transportation and facilities equipment to third parties. Operating Leases During the three months ended March 31, 2022 and 2021, we acted as a lessor in a revenue contract associated with the M/T American Phoenix, which is included in our marine transportation segment. Our lease revenues for this arrangement (inclusive of fixed and variable consideration) were $4.1 million and $3.4 million for the three months ended March 31, 2022 and 2021, respectively.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2022
Inventory Disclosure [Abstract]
Inventories	Inventories The major components of inventories were as follows: March 31, December 31, 2021 Petroleum products $ 795 $ 998 Crude oil 8,962 11,834 Caustic soda 6,654 5,690 NaHS 18,308 17,040 Raw materials - Alkali operations 7,760 7,599 Work-in-process - Alkali operations 10,058 7,496 Finished goods, net - Alkali operations 17,669 13,681 Materials and supplies, net - Alkali operations 13,888 13,620 Total $ 84,094 $ 77,958 Inventories are valued at the lower of cost or net realizable value. There was no adjustment to the net realizable value of inventories during the period ended March 31, 2022. As of December 31, 2021, the net realizable value of inventories were below cost by $2.0 million, which triggered a reduction of the value of inventory in our Consolidated Financial Statements by this amount. Materials and supplies include chemicals, maintenance supplies and spare parts which will be consumed in the mining of trona ore and production of soda ash processes.

Fixed Assets, Mineral Leasehold

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2022
Fixed Assets And Asset Retirement Obligations [Abstract]
Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	Fixed Assets, Mineral Leaseholds and Asset Retirement Obligations Fixed Assets Fixed assets consisted of the following: March 31, 2022 December 31, 2021 Crude oil and natural gas pipelines and related assets $ 2,840,622 $ 2,839,443 Alkali facilities, machinery and equipment 675,940 670,880 Onshore facilities, machinery and equipment 269,107 269,245 Transportation equipment 21,056 21,106 Marine vessels 1,018,919 1,018,284 Land, buildings and improvements 228,450 227,540 Office equipment, furniture and fixtures 26,535 23,965 Construction in progress 400,840 350,137 Other 37,586 43,440 Fixed assets, at cost 5,519,055 5,464,040 Less: Accumulated depreciation (1,607,285) (1,551,855) Net fixed assets $ 3,911,770 $ 3,912,185 Mineral Leaseholds Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: March 31, December 31, 2021 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (18,034) (17,014) Mineral leaseholds, net of accumulated depletion $ 547,985 $ 549,005 Our depreciation and depletion expense for the periods presented was as follows: Three Months Ended 2022 2021 Depreciation expense $ 65,750 $ 62,702 Depletion expense 1,020 912 Asset Retirement Obligations We record asset retirement obligations (“AROs”) in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations. The following table presents information regarding our AROs since December 31, 2021: ARO liability balance, December 31, 2021 $ 220,906 Accretion expense 3,447 Settlements (1,461) ARO liability balance, March 31, 2022 $ 222,892 At March 31, 2022 and December 31, 2021, $35.3 million and $36.3 million are included as current in “Accrued liabilities” on our Unaudited Condensed Consolidated Balance Sheets, respectively. The remainder of the ARO liability as of March 31, 2022 and December 31, 2021 is included in “Other long-term liabilities” on our Unaudited Condensed Consolidated Balance Sheets. With respect to our AROs, the following table presents our forecast of accretion expense for the periods indicated: Remainder of 2022 $ 9,486 2023 $ 10,583 2024 $ 9,767 2025 $ 10,469 2026 $ 8,216 Certain of our unconsolidated affiliates have AROs recorded at March 31, 2022 and December 31, 2021 relating to contractual agreements and regulatory requirements. In addition, certain entities that we consolidate have non-controlling interest owners that are responsible for their representative share of future costs of the related ARO liability . These amounts are immaterial to our Unaudited Condensed Consolidated Financial Statements.

Equity Investees

Equity Investees	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Investees	Equity Investees We account for our ownership in our joint ventures under the equity method of accounting. The price we pay to acquire an ownership interest in a company may exceed or be less than the underlying book value of the capital accounts we acquire. Such excess cost amounts are included within the carrying values of our equity investees. At March 31, 2022 and December 31, 2021, the unamortized excess cost amounts totaled $316.3 million and $319.9 million, respectively. We amortize the differences in carrying value as change in equity earnings. The following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees: Three Months Ended 2022 2021 Genesis’ share of operating earnings $ 16,010 $ 24,533 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,873) Net equity in earnings $ 12,444 $ 20,660 Distributions received (1) $ 19,018 $ 29,516 (1) Includes distributions attributable to the period and received during or promptly following such period. The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) (which we own 64% of and is our most significant equity investment): March 31, December 31, 2021 BALANCE SHEET DATA: Assets Current assets $ 15,869 $ 17,827 Fixed assets, net 156,464 160,379 Other assets 11,430 6,186 Total assets $ 183,763 $ 184,392 Liabilities and equity Current liabilities $ 7,436 $ 7,668 Other liabilities 233,066 231,970 Equity (Deficit) (56,739) (55,246) Total liabilities and equity $ 183,763 $ 184,392 Three Months Ended 2022 2021 STATEMENTS OF OPERATIONS DATA: Revenues $ 31,189 $ 42,413 Operating income $ 21,953 $ 32,161 Net income $ 20,907 $ 31,145 Poseidon’s Revolving Credit Facility

Intangible Assets

Intangible Assets	3 Months Ended
	Mar. 31, 2022
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets The following table summarizes the components of our intangible assets at the dates indicated: March 31, 2022 December 31, 2021 Gross Accumulated Carrying Gross Accumulated Carrying Marine contract intangibles $ 800 $ 616 $ 184 $ 800 $ 607 $ 193 Offshore pipeline contract intangibles 158,101 55,474 102,627 158,101 53,394 104,707 Other 40,240 16,268 23,972 37,933 15,770 22,163 Total $ 199,141 $ 72,358 $ 126,783 $ 196,834 $ 69,771 $ 127,063 Our amortization of intangible assets for the periods presented was as follows: Three Months Ended 2022 2021 Amortization of intangible assets $ 2,588 $ 2,600 We estimate that our amortization expense for the next five years will be as follows: Remainder of 2022 $ 8,988 2023 $ 11,733 2024 $ 11,368 2025 $ 11,143 2026 $ 10,843

Debt

Debt	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Debt	Debt Our obligations under debt arrangements consisted of the following: March 31, 2022 December 31, 2021 Principal Unamortized Premium and Debt Issuance Costs Net Value Principal Unamortized Premium and Debt Issuance Costs Net Value Senior secured credit facility-Revolving Loan (1) $ 94,800 $ — $ 94,800 $ 49,000 $ — $ 49,000 5.625% senior unsecured notes due 2024 341,135 1,892 339,243 341,135 2,106 339,029 6.500% senior unsecured notes due 2025 534,834 4,155 530,679 534,834 4,452 530,382 6.250% senior unsecured notes due 2026 359,799 3,215 356,584 359,799 3,410 356,389 8.000% senior unsecured notes due 2027 1,000,000 6,197 993,803 1,000,000 6,592 993,408 7.750% senior unsecured notes due 2028 720,975 9,281 711,694 720,975 9,678 711,297 Total long-term debt $ 3,051,543 $ 24,740 $ 3,026,803 $ 3,005,743 $ 26,238 $ 2,979,505 (1) Unamortized debt issuance costs associated with our Revolving Loan, as defined below (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were $4.2 million and $4.7 million as of March 31, 2022 and December 31, 2021, respectively. Senior Secured Credit Facility On April 8, 2021, we entered into the Fifth Amended and Restated Credit Agreement (our “new credit agreement”) to replace our Fourth Amended and Restated Credit Agreement. Our new credit agreement provides for a $950 million senior secured credit facility, comprised of a revolving loan facility with a borrowing capacity of $650 million (the “Revolving Loan”) and a term loan facility of $300 million (the “Term Loan”). The new credit agreement matures on March 15, 2024, subject to extension at our request for one Note 10 ). At March 31, 2022, the key terms for rates under our Revolving Loan (which are dependent on our leverage ratio as defined in the new credit agreement) are as follows: • The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate is equal to the sum of (a) the greatest 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 LIBOR rate for a one-month maturity on such day plus 1% and (b) the applicable margin. The Eurodollar rate is equal to the sum of (a) the LIBOR rate for the applicable interest period multiplied by the statutory reserve rate and (b) the applicable margin. The applicable margin varies from 2.25% to 3.75% on Eurodollar borrowings and from 1.25% to 2.75% on alternate base rate borrowings, depending on our leverage ratio. Our leverage ratio is recalculated quarterly and in connection with each material acquisition. At March 31, 2022, the applicable margins on our borrowings were 2.25% for alternate base rate borrowings and 3.25% for Eurodollar rate borrowings based on our leverage ratio. • Letter of credit fee rates range from 2.25% to 3.75% based on our leverage ratio as computed under the credit facility and can fluctuate quarterly. At March 31, 2022, our letter of credit rate was 3.25%. • We pay a commitment fee on the unused portion of the Revolving Loan. The commitment fee rates on the unused committed amount will range from 0.30% to 0.50% per annum depending on our leverage ratio. At March 31, 2022, our commitment fee rate on the unused committed amount was 0.50%. • We have the ability to increase the aggregate size of the Revolving Loan by an additional $200 million, subject to lender consent and certain other customary conditions. At March 31, 2022, we had $94.8 million outstanding under our Revolving Loan, with $7.1 million of the borrowed amount designated as a loan under the inventory sublimit. Our new credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which $1.5 million was outstanding at March 31, 2022. Due to the revolving nature of loans under our Revolving Loan, additional borrowings, periodic repayments and re-borrowings may be made until the maturity date. The total amount available for borrowings under our Revolving Loan at March 31, 2022 was $553.7 million, subject to compliance with covenants. Our new credit agreement does not include a “borrowing base” limitation except with respect to our inventory loans. Senior Unsecured Note Transactions On December 17, 2020, we issued $750 million in aggregate principal amount of our 8.00% senior unsecured notes due January 15, 2027 (the “2027 Notes”). Interest payments are due on January 15 and July 15 of each year with the initial interest payment due on July 15, 2021. The issuance generated net proceeds of approximately $737 million, net of issuance costs incurred. We used $316.5 million of the net proceeds to repay the portion of the 6.00% senior unsecured notes due May 15, 2023 (the “2023 Notes”) (including principal, accrued interest and tender premium) that were validly tendered, and the remaining proceeds were used to repay a portion of the borrowings outstanding under our revolving credit facility. On January 19, 2021, we redeemed the remaining principal balance outstanding on our 2023 Notes of $80.9 million in accordance with the terms and conditions of the indenture governing the 2023 Notes. We incurred a total loss of approximately $1.6 million relating to the extinguishment of our remaining 2023 Notes, inclusive of the redemption fee and the write-off of the related unamortized debt issuance costs, which is recorded in “Other expense” in our Unaudited Condensed Consolidated Statements of Operations for the three months ended March 31, 2021. On April 22, 2021, we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The notes constitute an additional issuance of our existing 2027 Notes that we issued on December 17, 2020 in an aggregate principal amount of $750 million. The additional $250 million of notes have identical terms as (other than with respect to the issue price) and constitute part of the same series of the 2027 Notes. The $250 million of the 2027 Notes were issued at a premium of 103.75% plus accrued interest from December 17, 2020. We used the net proceeds from the offering for general partnership purposes, including repaying a portion of the revolving borrowings outstanding under our new credit agreement.

Partners' Capital, Mezzanine Ca

Partners' Capital, Mezzanine Capital and Distributions	3 Months Ended
	Mar. 31, 2022
Equity [Abstract]
Partners' Capital, Mezzanine Capital and Distributions	Partners’ Capital, Mezzanine Capital and Distributions At March 31, 2022, our outstanding common units consisted of 122,539,221 Class A units and 39,997 Class B units. The Class A units are traditional common units in us. The Class B units are identical to the Class A units and, accordingly, have voting and distribution rights equivalent to those of the Class A units, and, in addition, the Class B units have the right to elect all of our board of directors and are convertible into Class A units under certain circumstances, subject to certain exceptions. At March 31, 2022, we had 25,336,778 Class A Convertible Preferred Units outstanding, which are discussed below in further detail. Distributions We paid or will pay the following cash distributions to our common unitholders in 2021 and 2022: Distribution For Date Paid Per Unit Total 2021 1 st Quarter May 14, 2021 $ 0.15 $ 18,387 2 nd Quarter August 13, 2021 $ 0.15 $ 18,387 3 rd Quarter November 12, 2021 $ 0.15 $ 18,387 4 th Quarter February 14, 2022 $ 0.15 $ 18,387 2022 1 st Quarter May 13, 2022 (1) $ 0.15 $ 18,387 (1) This distribution was declared on April 6, 2022 and will be paid to unitholders of record as of April 29, 2022. Class A Convertible Preferred Units Our Class A Convertible Preferred Units rank senior to all of our currently outstanding classes or series of limited partner interests with respect to distribution and/or liquidation rights. Holders of our Class A Convertible Preferred Units vote on an as-converted basis with holders of our common units and have certain class voting rights, including with respect to any amendment to the partnership agreement that would adversely affect the rights, preferences or privileges, or otherwise modify the terms, of those Class A Convertible Preferred Units. Accounting for the Class A Convertible Preferred Units Our Class A Convertible Preferred Units are considered redeemable securities under GAAP due to the existence of redemption provisions upon a deemed liquidation event that is outside our control. Therefore, we present them as temporary equity in the mezzanine section of the Unaudited Condensed Consolidated Balance Sheets. Because our Class A Convertible Preferred Units are not currently redeemable and we do not have plans or expect any events that constitute a change of control in our partnership agreement, we present our Class A Convertible Preferred Units at their initial carrying amount. However, we would be required to adjust that carrying amount if it becomes probable that we would be required to redeem our Class A Convertible Preferred Units. Initial and Subsequent Measurement We initially recognized our Class A Convertible Preferred Units at their issuance date fair value, net of issuance costs. We will not be required to adjust the carrying amount of our Class A Convertible Preferred Units until it becomes probable that they would become redeemable. Once redemption becomes probable, we would adjust the carrying amount of our Class A Convertible Preferred Units to the redemption value over a period of time comprising the date the feature first becomes probable and the date the units can first be redeemed. Our Class A Convertible Preferred Units contain a distribution Rate Reset Election (as defined in Note 1 5 ). This Rate Reset Election is bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period. Refer to Note 15 and Note 16 for additional discussion. Net Loss Attributable to Genesis Energy, L.P. is reduced by Class A Convertible Preferred Unit distributions that accumulated during the period and was reduced by $18.7 million for the three months ended March 31, 2022 and 2021. We paid or will pay the following cash distributions to our Class A Convertible Preferred unitholders in 2021 and 2022: Distribution For Date Paid Per Unit Total 2021 1 st Quarter May 14, 2021 $ 0.7374 $ 18,684 2 nd Quarter August 13, 2021 $ 0.7374 $ 18,684 3 rd Quarter November 12, 2021 $ 0.7374 $ 18,684 4 th Quarter February 14, 2022 $ 0.7374 $ 18,684 2022 1 st Quarter May 13, 2022 (1) $ 0.7374 $ 18,684 (1) This distribution was declared on April 6, 2022 and will be paid to unitholders of record as of April 29, 2022. Redeemable Noncontrolling Interests On September 23, 2019, we, through a subsidiary, Alkali Holdings, entered into an amended and restated Limited Liability Company Agreement of Alkali Holdings (the “LLC Agreement”) and a Securities Purchase Agreement (the “Securities Purchase Agreement”) whereby certain investment fund entities affiliated with Blackstone Alternative Credit Advisors LP, formerly known as “GSO Capital Partners LP” (collectively “BXC”) purchased $55.0 million (or 55,000 Alkali Holdings preferred units) and committed to purchase up to $350.0 million of Alkali Holdings preferred units, the entity that holds our trona and trona-based exploring, mining, processing, producing, marketing and selling business, including its Granger facility near Green River, Wyoming. Alkali Holdings has to date utilized the net proceeds from the preferred units to fund a portion of the anticipated cost of expansion of the Granger facility (the “Granger Optimization Project” or “GOP”). On April 14, 2020, we entered into an amendment to our agreements with BXC to, among other things, extend the construction timeline of the GOP by one year, which we currently anticipate completing in the second half of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to BXC, which was accounted for as issuance costs. As part of the amendment, the commitment period was increased to four years, and the total commitment of BXC was increased to, subject to compliance with the covenants contained in the agreements with BXC, up to $351.8 million preferred units (or 351,750 preferred units) in Alkali Holdings. As of March 31, 2022, there are 250,114 Alkali Holdings preferred units outstanding. From time to time after we have drawn at least $251.8 million, we have the option to redeem the outstanding preferred units in whole for cash at a price equal to the initial $1,000 per preferred unit purchase price, plus no less than the greater of a predetermined fixed internal rate of return amount or a multiple of invested capital metric, net of cash distributions paid to date (“Base Preferred Return”). Additionally, if all outstanding preferred units are being redeemed, we have not drawn at least $251.8 million, and BXC is not a “defaulting member” under the LLC Agreement, BXC has the right to a make-whole amount on the number of undrawn preferred units. Accounting for Redeemable Noncontrolling Interests Classification The Alkali Holdings preferred units issued and outstanding are accounted for as a redeemable noncontrolling interest in the mezzanine section on our Unaudited Condensed Consolidated Balance Sheets due to the redemption features for a change of control. Initial and Subsequent Measurement We recorded the Alkali Holdings preferred units at their issuance date fair value, net of issuance costs. The fair value as of March 31, 2022 represents the carrying amount based on the issued and outstanding Alkali Holdings preferred units most probable redemption event on the six and a half year anniversary of the closing, which is the predetermined internal rate of return measure accreted using the effective interest method to the redemption value as of the reporting date. Net Loss Attributable to Genesis Energy, L.P. for the three months ended March 31, 2022 includes $7.8 million of adjustments, of which $6.6 million was allocated to the paid-in-kind (“PIK”) distributions on the outstanding Alkali Holdings preferred units and $1.2 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the three months ended March 31, 2021 includes $4.8 million of adjustments, of which $4.1 million was allocated to the PIK distributions and $0.7 million was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended March 31, 2022 in-kind to our Alkali Holdings preferred unitholders. The unitholders’ liquidation preference is increased by new issuances and PIK distributions and is reduced by tax distributions paid to the unitholders, which are required to be paid by us to fulfill the income tax liabilities of each holder of Alkali Holdings preferred units. As of the reporting date, there are no triggering, change of control, early redemption or monetization events that are probable that would require us to revalue the Alkali Holdings preferred units. If the Alkali Holdings preferred units were redeemed on the reporting date of March 31, 2022, the redemption amount would be equal to $289.8 million, which would be the multiple of invested capital metric applied to the Alkali Holdings preferred units outstanding plus the make-whole amount on the undrawn minimum Alkali Holdings preferred units. The following table shows the change in our redeemable noncontrolling interest balance from December 31, 2021 to March 31, 2022: Balance as of December 31, 2021 $ 259,568 Issuance of preferred units, net of issuance costs (1) 3,646 PIK distribution 6,596 Redemption accretion 1,227 Tax distributions (1) (3,795) Balance as of March 31, 2022 $ 267,242 (1) During the period ended March 31, 2022, we issued 3,720 Alkali Holdings preferred units to BXC to satisfy the Company’s obligation to pay tax distributions. Noncontrolling Interests On November 17, 2021, we, through a subsidiary, sold 36% of the membership interests in CHOPS for proceeds of approximately $418 million. We retained 64% of the membership interests in CHOPS and remain the operator of the CHOPS pipeline and associated assets. 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	3 Months Ended
	Mar. 31, 2022
Net Income per Common Unit [Abstract]
Net Loss Per Common Unit	Net Loss Per Common Unit Basic net loss per common unit is computed by dividing Net Loss Attributable to Genesis Energy, L.P., after considering income attributable to our Class A preferred unitholders, by the weighted average number of common units outstanding. The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Under the if-converted method, the Class A Convertible Preferred Units are assumed to be converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted net income per common unit calculation for the period being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. For the three months ended March 31, 2022 and 2021, the effect of the assumed conversion of the 25,336,778 Class A Convertible Preferred Units was anti-dilutive and was not included in the computation of diluted earnings per unit. The following table reconciles Net loss attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net loss per common unit (in thousands): Three Months Ended 2022 2021 Net loss attributable to Genesis Energy, L.P. $ (5,250) $ (34,224) Less: Accumulated distributions attributable to Class A Convertible Preferred Units (18,684) (18,684) Net loss attributable to common unitholders $ (23,934) $ (52,908) Weighted average outstanding units 122,579 122,579 Basic and diluted net loss per common unit $ (0.20) $ (0.43)

Business Segment Information

Business Segment Information	3 Months Ended
	Mar. 31, 2021
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information We currently manage our businesses through four divisions that constitute our reportable segments: • Offshore pipeline transportation – offshore transportation of crude oil and natural gas in the Gulf of Mexico; • Sodium minerals and sulfur services – trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as the processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and the selling of the related by-product, NaHS; • Onshore facilities and transportation – terminalling, blending, storing, marketing and transporting crude oil and petroleum products (primarily fuel oil, asphalt and other heavy refined products); and • Marine transportation – marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America. Substantially all of our revenues are derived from, and substantially all of our assets are located in, the United States. We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash gains and charges, such as depreciation, depletion, amortization and accretion) and segment general and administrative expenses, net of the effects of our noncontrolling interests, plus our equity in distributable cash generated by our equity investees. In addition, our Segment Margin definition excludes the non-cash effects of our long-term incentive compensation plan and includes the non-income portion of payments received under our previously owned direct financing lease. Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes, where relevant, and capital investment. Segment information for the periods presented below was as follows: Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Onshore Facilities & Transportation Marine Transportation Total Three Months Ended March 31, 2022 Segment Margin (1) $ 70,904 $ 67,375 $ 7,036 $ 12,137 $ 157,452 Capital expenditures (2) $ 35,441 $ 26,326 $ 737 $ 10,059 $ 72,563 Revenues: External customers $ 68,068 $ 288,008 $ 220,295 $ 55,576 $ 631,947 Intersegment (3) — (2,334) 2,136 198 — Total revenues of reportable segments $ 68,068 $ 285,674 $ 222,431 $ 55,774 $ 631,947 Three Months Ended March 31, 2021 Segment Margin (1) $ 84,269 $ 43,720 $ 20,999 $ 7,109 $ 156,097 Capital expenditures (2) $ 11,528 $ 10,038 $ 1,099 $ 11,714 $ 34,379 Revenues: External customers $ 64,384 $ 229,306 $ 188,150 $ 39,379 $ 521,219 Intersegment (3) — (2,019) 1,067 952 — Total revenues of reportable segments $ 64,384 $ 227,287 $ 189,217 $ 40,331 $ 521,219 (1) A reconciliation of Net 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: March 31, December 31, 2021 Offshore pipeline transportation $ 2,101,728 $ 2,103,140 Sodium minerals and sulfur services 2,149,589 2,132,588 Onshore facilities and transportation 1,014,005 923,064 Marine transportation 698,209 703,030 Other assets 55,668 43,979 Total consolidated assets $ 6,019,199 $ 5,905,801 Reconciliation of Net loss attributable to Genesis Energy, L.P. to total Segment Margin: Three Months Ended 2022 2021 Net loss attributable to Genesis Energy, L.P. $ (5,250) $ (34,224) Corporate general and administrative expenses 15,721 11,152 Depreciation, depletion, amortization and accretion 72,948 68,997 Interest expense 55,104 57,829 Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) 6,574 8,856 Other non-cash items (2) (3,571) 18,444 Distribution from unrestricted subsidiaries not included in income (3) — 17,500 Loss on extinguishment of debt (4) — 1,627 Differences in timing of cash receipts for certain contractual arrangements (5) 8,230 299 Change in provision for leased items no longer in use (431) 604 Redeemable noncontrolling interest redemption value adjustments (6) 7,823 4,791 Income tax expense 304 222 Total Segment Margin $ 157,452 $ 156,097 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The three months ended March 31, 2022 includes $6.2 million in unrealized gains from the valuation of our commodity derivative transactions (excluding fair value hedges) and an unrealized loss of $4.3 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three months ended March 31, 2021 includes an unrealized loss of $18.4 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. Refer to Note 1 5 and Note 16 for details. (3) The three months ended March 31, 2021 include $17.5 million in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. We received the principal payment associated with our previously owned NEJD pipeline in the fourth quarter of 2021. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility. (4) Refer to Note 9 for details surrounding the extinguishment of our 2023 Notes. (5) Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. (6) Includes PIK distributions attributable to the period and accretion on the redemption feature.

Transactions with Related Parti

Transactions with Related Parties	3 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
Transactions with Related Parties	Transactions with Related Parties The transactions with related parties were as follows: Three Months Ended 2022 2021 Revenues: Revenues from services and fees to Poseidon (1) $ 3,238 $ 3,786 Revenues from product sales to ANSAC 88,182 67,955 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon (1) 255 240 Charges for services from ANSAC 845 178 (1) We own a 64% interest in Poseidon. Our CEO, Mr. Sims, owns an aircraft which is used by us for business purposes in the course of operations. We pay Mr. Sims a fixed monthly fee and reimburse the aircraft management company for costs related to our usage of the aircraft, including fuel and the actual out-of-pocket costs. Based on current market rates for chartering of private aircraft under long-term, priority arrangements with industry recognized chartering companies, we believe that the terms of this arrangement are no worse than what we could have expected to obtain in an arms-length transaction. Transactions with Unconsolidated Affiliates Poseidon We provide management, administrative and pipeline operator services to Poseidon under an Operation and Management Agreement. Currently, that agreement automatically renews annually unless terminated by either party (as defined in the agreement). Our revenues for the three months ended March 31, 2022 and 2021 include $2.4 million and $2.4 million, respectively, of fees we earned through the provision of services under that agreement. At March 31, 2022 and December 31, 2021, Poseidon owed us $1.3 million and $2.4 million, respectively, for services rendered. ANSAC We (through a subsidiary of our Alkali Business) are a member of the American Natural Soda Ash Corp. (“ANSAC”), an organization whose purpose is promoting and increasing the use and sale of natural soda ash and other refined or processed sodium products produced in the U.S. and consumed in specified countries outside of the U.S. Members sell products to ANSAC to satisfy ANSAC’s sales commitments to its customers. ANSAC passes its costs through to its members using a pro rata calculation based on sales. Those costs include sales and marketing, employees, office supplies, professional fees, travel, rent and certain other costs. Those transactions do not necessarily represent arm's length transactions and may not represent all costs we would otherwise incur if we operated our Alkali Business on a stand-alone basis. We also benefit from favorable shipping rates for our direct exports when using ANSAC to arrange for ocean transport. ANSAC is considered a variable interest entity (VIE) because we experience certain risks and rewards from our relationship with them. As we do not exercise control over ANSAC and are not considered its primary beneficiary, we do not consolidate ANSAC. The ANSAC membership agreement provides that in the event an ANSAC member exits or the ANSAC cooperative is dissolved, the exiting members are obligated for their respective portion of the residual net assets or deficit of the cooperative. As of March 31, 2022, such amount is not material to us. Net Sales to ANSAC were $88.2 million during the three months ended March 31, 2022 and were $68.0 million during the three months ended March 31, 2021. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $0.8 million during the three months ended March 31, 2022 and were $0.2 million during the three months ended March 31, 2021. Receivables from and payables to ANSAC as of March 31, 2022 and December 31, 2021 are as follows: March 31, December 31, 2022 2021 Accounts receivable - trade, net: ANSAC $ 68,758 $ 64,799 Accounts payable - trade: ANSAC $ 845 $ 116

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2022
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended 2022 2021 (Increase) decrease in: Accounts receivable $ (131,249) $ (99,504) Inventories (282) 27,450 Deferred charges 12,805 7,731 Other current assets (2,677) (2,294) Increase (decrease) in: Accounts payable 107,747 38,994 Accrued liabilities (15,513) 22,561 Net changes in components of operating assets and liabilities $ (29,169) $ (5,062) Payments of interest and commitment fees were $69.8 million and $35.4 million for the three months ended March 31, 2022 and March 31, 2021, respectively. The increase in interest payments during 2022 is primarily related to the timing of interest payments on our senior unsecured notes, specifically our 2027 Notes, as we made an interest payment in January 2022. The first interest payment made on our 2027 Notes was in July 2021. We capitalized interest of $2.0 million and $0.7 million during the three months ended March 31, 2022 and March 31, 2021, respectively. At March 31, 2022 and March 31, 2021, we had incurred liabilities for fixed and intangible asset additions totaling $45.0 million and $27.1 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 increase in this amount is principally due to the increase in capital expenditures associated with our GOP ( Note 10 ) and certain of our offshore growth capital expenditures.

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Commodity Derivatives We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (exchange-traded futures, options and swap contracts) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil, natural gas and petroleum products. Our decision as to whether to designate derivative instruments as fair value hedges for accounting purposes relates to our expectations of the length of time we expect to have the commodity price exposure and our expectations as to whether the derivative contract will qualify as highly effective under accounting guidance in limiting our exposure to commodity price risk. Most of the petroleum products, including fuel oil that we supply, cannot be hedged with a high degree of effectiveness with exchange-traded derivative contracts; therefore, we do not designate derivative contracts utilized to limit our price risk related to petroleum products as hedges for accounting purposes. Typically, we utilize crude oil and other petroleum products futures and option contracts to limit our exposure to the effect of fluctuations in petroleum products prices on the future sale of our inventory or commitments to purchase petroleum products, and we recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. The recognition of changes in fair value of the derivative contracts not designated as hedges for accounting purposes can occur in reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore, we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed. We have designated certain crude oil futures contracts as hedges of crude oil inventory due to our expectation that these contracts will be highly effective in hedging our exposure to fluctuations in crude oil prices during the period that we expect to hold that inventory. We account for these derivative instruments as fair value hedges under the accounting guidance. Changes in the fair value of these derivative instruments designated as fair value hedges are used to offset related changes in the fair value of the hedged crude oil inventory. Any hedge ineffectiveness in these fair value hedges and any amounts excluded from effectiveness testing are recorded as a gain or loss within “Onshore facilities and transportation costs - product costs” in the Unaudited Condensed Consolidated Statements of Operations. In accordance with exchange requirements, we fund the margin associated with our exchange-traded commodity derivative contracts. The amount of the margin is adjusted daily based on the fair value of the commodity derivative contracts. Margin requirements are intended to mitigate a party’s exposure to market volatility and counterparty credit risk. We offset fair value amounts recorded for our exchange-traded derivative contracts against required margin funding in “Current Assets - Other” in our Unaudited Condensed Consolidated Balance Sheets. Additionally, we utilize swap arrangements. Our Alkali Business relies on natural gas to generate heat and electricity for operations. We use a combination of commodity price swap contracts, future purchase contracts and option contracts to manage our exposure to fluctuations in natural gas prices. The swap contracts fix the basis differential between NYMEX Henry Hub and NW Rocky Mountain posted prices. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of natural gas derivative contracts as increases or decreases within “Sodium minerals and sulfur services operating costs” in the Unaudited Condensed Consolidated Statements of Operations. At March 31, 2022, we had the following outstanding commodity derivative commodity contracts that were entered into to economically hedge inventory, fixed price purchase commitments or forecasted purchases. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 62 — Weighted average contract price per Bbl $ 103.28 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 54 51 Weighted average contract price per Bbl $ 107.63 $ 107.92 Natural gas swaps: Contract volumes (10,000 MMBtu) — 367 Weighted average price differential per MMBtu $ — $ 0.03 Natural gas futures: Contract volumes (10,000 MMBtu) 155 459 Weighted average contract price per MMBtu $ 4.91 $ 4.14 Natural gas options Contract volumes (10,000 MMBtu) 26 8 Weighted average premium received/paid $ 0.16 $ 0.03 Crude oil options: Contract volumes (1,000 Bbls) 8 — Weighted average premium received/paid $ 12.47 $ — Financial Statement Impacts Unrealized gains are subtracted from net income and unrealized losses are added to net income in determining cash flows from operating activities. To the extent that we have fair value hedges outstanding, the offsetting change recorded in the fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in the cash margin balance required to maintain our exchange-traded derivative contracts also affect cash flows from operating activities. The following tables reflect the estimated fair value position of our derivatives at March 31, 2022 and December 31, 2021: Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, 2021 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Other 300 1,867 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 6,856 $ 310 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (837) (310) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ 6,019 $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized assets Current Assets - Other $ 688 $ 49 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (504) (49) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ 184 $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (87,468) (52,372) Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued Liabilities (946) (608) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (837) $ (2,380) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 837 2,380 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (504) $ (209) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 504 209 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — (1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under “Current Assets - Other”. (2) Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative. Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists. Accordingly, we also offset derivative assets and liabilities with our cash margin balance. Our exchange-traded derivatives are transacted through brokerage accounts and are subject to margin requirements as established by the respective exchange. On a daily basis, our account equity (consisting of the sum of our cash margin balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin. As of March 31, 2022, we had a net broker receivable of approximately $3.8 million (consisting of initial margin of $2.0 million increased by $1.8 million variation margin). As of December 31, 2021, we had a net broker receivable of approximately $2.9 million (consisting of initial margin of $2.1 million increased by $0.8 million of variation margin). At March 31, 2022 and December 31, 2021, none of our outstanding derivatives contained credit-risk related contingent features that would result in a material adverse impact to us upon any change in our credit ratings. Preferred Distribution Rate Reset Election A derivative feature embedded in a contract that does not meet the definition of a derivative in its entirety must be bifurcated and accounted for separately if the economic characteristics and risks of the embedded derivative are not clearly and closely related to those of the host contract. For a period of 30 days following (i) September 1, 2022 and (ii) each subsequent anniversary thereof, the holders of our Class A Convertible Preferred Units may make a one-time election to reset the quarterly distribution amount (a “Rate Reset Election”) to a cash amount per Class A Convertible Preferred Unit equal to the amount that would be payable per quarter if a Class A Convertible Preferred Unit accrued interest on the Issue Price at an annualized rate equal to three-month LIBOR plus 750 basis points; provided, however, that such reset rate shall be equal to 10.75% if (i) such alternative rate is higher than the LIBOR-based rate and (ii) the then market price for our common units is then less than 110% of the Issue Price. The Rate Reset Election of our Class A Convertible Preferred Units represents an embedded derivative that must be bifurcated from the related host contract and recorded at fair value on our Unaudited Condensed Consolidated Balance Sheet. Corresponding changes in fair value are recognized in “Other income (expense)” in our Unaudited Condensed Consolidated Statement of Operations. At March 31, 2022, the fair value of this embedded derivative was a liability of $87.5 million. See Note 10 for additional information regarding our Class A Convertible Preferred Units and the Rate Reset Election. Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended 2022 2021 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (1,170) $ (5,897) Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs 6,048 (3,921) Total commodity derivatives $ 4,878 $ (9,818) Natural Gas Swap Sodium minerals and sulfur services operating costs $ (1,102) $ (67) Preferred Distribution Rate Reset Election Other expense $ (4,258) $ (18,438)

Fair-Value Measurements

Fair-Value Measurements	3 Months Ended
	Mar. 31, 2022
Fair Value Disclosures [Abstract]
Fair-Value Measurements	Fair-Value Measurements We classify financial assets and liabilities into the following three levels based on the inputs used to measure fair value: (1) Level 1 fair values are based on observable inputs such as quoted prices in active markets for identical assets and liabilities; (2) Level 2 fair values are based on pricing inputs other than quoted prices in active markets for identical assets and liabilities and are either directly or indirectly observable as of the measurement date; and (3) Level 3 fair values are based on unobservable inputs in which little or no market data exists. As required by fair value accounting guidance, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value requires judgment and may affect the placement of assets and liabilities within the fair value hierarchy levels. The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021. March 31, 2022 December 31, 2021 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 7,544 $ 300 $ — $ 359 $ 1,867 $ — Liabilities $ (1,341) $ (946) $ — $ (2,589) $ (608) $ — Preferred Distribution Rate Reset Election $ — $ — $ (87,468) $ — $ — $ (83,210) Rollforward of Level 3 Fair Value Measurements The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3: Balance as of December 31, 2021 $ (83,210) Net loss for the period included in earnings (4,258) Balance as of March 31, 2022 $ (87,468) Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy. The fair value of the swaps contracts was determined using market price quotations and a pricing model. The swap contracts were considered a level 2 input in the fair value hierarchy at March 31, 2022. The fair value of the embedded derivative feature is based on a valuation model that estimates the fair value of our Class A Convertible Preferred Units with and without a Rate Reset Election. This model contains inputs, including our common unit price relative to the issuance price, the current dividend yield, the discount yield (which is adjusted periodically for relevant changes associated with the industry’s credit markets), default probabilities, equity volatility, U.S. Treasury yields and timing estimates which involve management judgment. Our equity volatility rate used to value our embedded derivative feature was 50% at March 31, 2022. A significant increase or decrease in the value of these inputs could result in a material change in fair value to this embedded derivative feature. Due to a decrease in our discount yield compared to the preceding quarter, we recorded an unrealized loss of $4.3 million for the three months ended March 31, 2022. Due to a decrease in our discount yield compared to preceding quarter, we recorded an unrealized loss of $18.4 million for the three months ended March 31, 2021. These effects are all recorded within “Other expense” on the Unaudited Condensed Consolidated Statements of Operations. See Note 15 for additional information on our derivative instruments. Other Fair Value Measurements We believe the debt outstanding under our senior secured credit facility approximates fair value as the stated rate of interest approximates current market rates of interest for similar instruments with comparable maturities. At March 31, 2022 and December 31, 2021 our senior unsecured notes had a carrying value and fair value of approximately $3.0 billion. 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.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2022
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	3 Months Ended
	Mar. 31, 2022
Subsequent Events [Abstract]
Subsequent Events	Subsequent EventsOn April 29, 2022, we entered into an agreement to sell our Independence Hub platform to a producer group in the Gulf of Mexico for gross proceeds of $40 million, of which $8 million, or 20%, is attributable and paid to our noncontrolling interest holders. We will recognize a gain of approximately $40 million, of which $8 million, or 20%, is attributable to our noncontrolling interest holders, in the second quarter 2022, as the platform asset sold had essentially no book value at the time of the sale.

Recent Accounting Developments

Recent Accounting Developments (Policies)	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
Basis of Presentation and Consolidation	Basis of Presentation and Consolidation The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including our general partner, Genesis Energy, LLC. Our results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the fiscal year. The Unaudited Condensed Consolidated Financial Statements included herein have been prepared by us without audit pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Accordingly, they reflect all adjustments (which consist solely of normal recurring adjustments) that are, in the opinion of management, necessary for a fair presentation of the financial results for interim periods. Certain information and notes normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to such rules and regulations. However, we believe that the disclosures are adequate to make the information presented not misleading when read in conjunction with the information contained in the periodic reports we file with the SEC pursuant to the Securities Exchange Act of 1934, including the Consolidated Financial Statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2021 (our “Annual Report”). Except per unit amounts, or as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars.
Recent and Proposed Accounting Pronouncements	Recent and Proposed Accounting Pronouncements In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848), which provides expedients and exceptions for accounting treatment of contracts which are affected by the anticipated discontinuation of the London InterBank Offered Rate (“LIBOR”) and other rates resulting from rate reform that are entered into on or before December 31, 2022. Contract terms that are modified due to the replacement of a reference rate are not required to be remeasured or reassessed under relevant accounting standards. The discontinuation of LIBOR is expected to occur in 2023. We are evaluating the provisions of ASU 2020-04 and have not yet determined the impact on our Consolidated Financial Statements and disclosures related to our senior secured credit facility due to the uncertain timing of the transition to another interest rate benchmark.

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and 2021, respectively: Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 68,068 $ — $ 55,774 $ 13,631 $ 137,473 Product Sales — 258,775 — 208,800 467,575 Refinery Services — 26,899 — — 26,899 $ 68,068 $ 285,674 $ 55,774 $ 222,431 $ 631,947 Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities and Transportation Consolidated Fee-based revenues $ 64,384 $ — $ 40,331 $ 24,394 $ 129,109 Product Sales — 204,778 — 164,823 369,601 Refinery Services — 22,509 — — 22,509 $ 64,384 $ 227,287 $ 40,331 $ 189,217 $ 521,219
Schedule of Contract Asset and Liabilities Balances Activity	The table below depicts our contract asset and liability balances at December 31, 2021 and March 31, 2022: Contract Assets Contract Liabilities Current Assets- Other Accrued Liabilities Other Long-Term Liabilities Balance at December 31, 2021 $ 13,563 $ 2,619 $ 19,028 Balance at March 31, 2022 4,687 2,415 18,498
Schedule of Revenue Expected to be Recognized in Future Periods	The following chart depicts how we expect to recognize revenues for future periods related to these contracts: Offshore Pipeline Transportation Onshore Facilities and Transportation Remainder of 2022 $ 55,635 $ 5,400 2023 65,645 7,200 2024 59,034 1,800 2025 62,699 — 2026 44,691 — Thereafter 57,612 — Total $ 345,316 $ 14,400

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Major Components of Inventories	The major components of inventories were as follows: March 31, December 31, 2021 Petroleum products $ 795 $ 998 Crude oil 8,962 11,834 Caustic soda 6,654 5,690 NaHS 18,308 17,040 Raw materials - Alkali operations 7,760 7,599 Work-in-process - Alkali operations 10,058 7,496 Finished goods, net - Alkali operations 17,669 13,681 Materials and supplies, net - Alkali operations 13,888 13,620 Total $ 84,094 $ 77,958

Fixed Assets, Mineral Leaseho_2

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2022
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule of Fixed Assets	Fixed assets consisted of the following: March 31, 2022 December 31, 2021 Crude oil and natural gas pipelines and related assets $ 2,840,622 $ 2,839,443 Alkali facilities, machinery and equipment 675,940 670,880 Onshore facilities, machinery and equipment 269,107 269,245 Transportation equipment 21,056 21,106 Marine vessels 1,018,919 1,018,284 Land, buildings and improvements 228,450 227,540 Office equipment, furniture and fixtures 26,535 23,965 Construction in progress 400,840 350,137 Other 37,586 43,440 Fixed assets, at cost 5,519,055 5,464,040 Less: Accumulated depreciation (1,607,285) (1,551,855) Net fixed assets $ 3,911,770 $ 3,912,185
Schedule of Mineral Leaseholds	Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: March 31, December 31, 2021 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (18,034) (17,014) Mineral leaseholds, net of accumulated depletion $ 547,985 $ 549,005
Schedule of Depreciation and Depletion Expense	Our depreciation and depletion expense for the periods presented was as follows: Three Months Ended 2022 2021 Depreciation expense $ 65,750 $ 62,702 Depletion expense 1,020 912
Schedule of Change in Asset Retirement Obligation	The following table presents information regarding our AROs since December 31, 2021: ARO liability balance, December 31, 2021 $ 220,906 Accretion expense 3,447 Settlements (1,461) ARO liability balance, March 31, 2022 $ 222,892
Schedule of Forecast of Accretion Expense of Asset Retirement Obligations	With respect to our AROs, the following table presents our forecast of accretion expense for the periods indicated: Remainder of 2022 $ 9,486 2023 $ 10,583 2024 $ 9,767 2025 $ 10,469 2026 $ 8,216

Equity Investees (Tables)

Equity Investees (Tables)	3 Months Ended
	Mar. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Consolidated Financial Statements Related to Equity Investees	The following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees: Three Months Ended 2022 2021 Genesis’ share of operating earnings $ 16,010 $ 24,533 Amortization of differences attributable to Genesis’ carrying value of equity investments (3,566) (3,873) Net equity in earnings $ 12,444 $ 20,660 Distributions received (1) $ 19,018 $ 29,516 (1) Includes distributions attributable to the period and received during or promptly following such period.
Schedule of Balance Sheet Information for Equity Investees	The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) (which we own 64% of and is our most significant equity investment): March 31, December 31, 2021 BALANCE SHEET DATA: Assets Current assets $ 15,869 $ 17,827 Fixed assets, net 156,464 160,379 Other assets 11,430 6,186 Total assets $ 183,763 $ 184,392 Liabilities and equity Current liabilities $ 7,436 $ 7,668 Other liabilities 233,066 231,970 Equity (Deficit) (56,739) (55,246) Total liabilities and equity $ 183,763 $ 184,392
Schedule Of Operations For Equity Investees	Three Months Ended 2022 2021 STATEMENTS OF OPERATIONS DATA: Revenues $ 31,189 $ 42,413 Operating income $ 21,953 $ 32,161 Net income $ 20,907 $ 31,145

Intangible Assets (Tables)

Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2022
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of Components of Intangible Assets	The following table summarizes the components of our intangible assets at the dates indicated: March 31, 2022 December 31, 2021 Gross Accumulated Carrying Gross Accumulated Carrying Marine contract intangibles $ 800 $ 616 $ 184 $ 800 $ 607 $ 193 Offshore pipeline contract intangibles 158,101 55,474 102,627 158,101 53,394 104,707 Other 40,240 16,268 23,972 37,933 15,770 22,163 Total $ 199,141 $ 72,358 $ 126,783 $ 196,834 $ 69,771 $ 127,063
Schedule of Amortization Expense	Our amortization of intangible assets for the periods presented was as follows: Three Months Ended 2022 2021 Amortization of intangible assets $ 2,588 $ 2,600
Schedule of Expected Amortization Expense	We estimate that our amortization expense for the next five years will be as follows: Remainder of 2022 $ 8,988 2023 $ 11,733 2024 $ 11,368 2025 $ 11,143 2026 $ 10,843

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Schedule of Debt	Our obligations under debt arrangements consisted of the following: March 31, 2022 December 31, 2021 Principal Unamortized Premium and Debt Issuance Costs Net Value Principal Unamortized Premium and Debt Issuance Costs Net Value Senior secured credit facility-Revolving Loan (1) $ 94,800 $ — $ 94,800 $ 49,000 $ — $ 49,000 5.625% senior unsecured notes due 2024 341,135 1,892 339,243 341,135 2,106 339,029 6.500% senior unsecured notes due 2025 534,834 4,155 530,679 534,834 4,452 530,382 6.250% senior unsecured notes due 2026 359,799 3,215 356,584 359,799 3,410 356,389 8.000% senior unsecured notes due 2027 1,000,000 6,197 993,803 1,000,000 6,592 993,408 7.750% senior unsecured notes due 2028 720,975 9,281 711,694 720,975 9,678 711,297 Total long-term debt $ 3,051,543 $ 24,740 $ 3,026,803 $ 3,005,743 $ 26,238 $ 2,979,505 (1) Unamortized debt issuance costs associated with our Revolving Loan, as defined below (included in “Other Assets, net of amortization” on the Unaudited Condensed Consolidated Balance Sheets), under our senior secured credit facility were $4.2 million and $4.7 million as of March 31, 2022 and December 31, 2021, respectively.

Partners' Capital, Mezzanine _2

Partners' Capital, Mezzanine Capital and Distributions (Tables)	3 Months Ended
	Mar. 31, 2022
Equity [Abstract]
Schedule of Paid Distributions	We paid or will pay the following cash distributions to our common unitholders in 2021 and 2022: Distribution For Date Paid Per Unit Total 2021 1 st Quarter May 14, 2021 $ 0.15 $ 18,387 2 nd Quarter August 13, 2021 $ 0.15 $ 18,387 3 rd Quarter November 12, 2021 $ 0.15 $ 18,387 4 th Quarter February 14, 2022 $ 0.15 $ 18,387 2022 1 st Quarter May 13, 2022 (1) $ 0.15 $ 18,387 (1) This distribution was declared on April 6, 2022 and will be paid to unitholders of record as of April 29, 2022. We paid or will pay the following cash distributions to our Class A Convertible Preferred unitholders in 2021 and 2022: Distribution For Date Paid Per Unit Total 2021 1 st Quarter May 14, 2021 $ 0.7374 $ 18,684 2 nd Quarter August 13, 2021 $ 0.7374 $ 18,684 3 rd Quarter November 12, 2021 $ 0.7374 $ 18,684 4 th Quarter February 14, 2022 $ 0.7374 $ 18,684 2022 1 st Quarter May 13, 2022 (1) $ 0.7374 $ 18,684 (1) This distribution was declared on April 6, 2022 and will be paid to unitholders of record as of April 29, 2022.
Schedule of Changes in Redeemable Noncontrolling Interest	The following table shows the change in our redeemable noncontrolling interest balance from December 31, 2021 to March 31, 2022: Balance as of December 31, 2021 $ 259,568 Issuance of preferred units, net of issuance costs (1) 3,646 PIK distribution 6,596 Redemption accretion 1,227 Tax distributions (1) (3,795) Balance as of March 31, 2022 $ 267,242 (1) During the period ended March 31, 2022, we issued 3,720 Alkali Holdings preferred units to BXC to satisfy the Company’s obligation to pay tax distributions.

Net Loss Per Common Unit (Table

Net Loss Per Common Unit (Tables)	3 Months Ended
	Mar. 31, 2022
Net Income per Common Unit [Abstract]
Schedule of Computation of Earnings Per Share, Basic and Diluted	The following table reconciles Net loss attributable to Genesis Energy, L.P. and weighted average units used in computing basic and diluted net loss per common unit (in thousands): Three Months Ended 2022 2021 Net loss attributable to Genesis Energy, L.P. $ (5,250) $ (34,224) Less: Accumulated distributions attributable to Class A Convertible Preferred Units (18,684) (18,684) Net loss attributable to common unitholders $ (23,934) $ (52,908) Weighted average outstanding units 122,579 122,579 Basic and diluted net loss per common unit $ (0.20) $ (0.43)

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Mar. 31, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Segment information for the periods presented below was as follows: Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Onshore Facilities & Transportation Marine Transportation Total Three Months Ended March 31, 2022 Segment Margin (1) $ 70,904 $ 67,375 $ 7,036 $ 12,137 $ 157,452 Capital expenditures (2) $ 35,441 $ 26,326 $ 737 $ 10,059 $ 72,563 Revenues: External customers $ 68,068 $ 288,008 $ 220,295 $ 55,576 $ 631,947 Intersegment (3) — (2,334) 2,136 198 — Total revenues of reportable segments $ 68,068 $ 285,674 $ 222,431 $ 55,774 $ 631,947 Three Months Ended March 31, 2021 Segment Margin (1) $ 84,269 $ 43,720 $ 20,999 $ 7,109 $ 156,097 Capital expenditures (2) $ 11,528 $ 10,038 $ 1,099 $ 11,714 $ 34,379 Revenues: External customers $ 64,384 $ 229,306 $ 188,150 $ 39,379 $ 521,219 Intersegment (3) — (2,019) 1,067 952 — Total revenues of reportable segments $ 64,384 $ 227,287 $ 189,217 $ 40,331 $ 521,219 (1) A reconciliation of Net 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: March 31, December 31, 2021 Offshore pipeline transportation $ 2,101,728 $ 2,103,140 Sodium minerals and sulfur services 2,149,589 2,132,588 Onshore facilities and transportation 1,014,005 923,064 Marine transportation 698,209 703,030 Other assets 55,668 43,979 Total consolidated assets $ 6,019,199 $ 5,905,801 Reconciliation of Net loss attributable to Genesis Energy, L.P. to total Segment Margin: Three Months Ended 2022 2021 Net loss attributable to Genesis Energy, L.P. $ (5,250) $ (34,224) Corporate general and administrative expenses 15,721 11,152 Depreciation, depletion, amortization and accretion 72,948 68,997 Interest expense 55,104 57,829 Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) 6,574 8,856 Other non-cash items (2) (3,571) 18,444 Distribution from unrestricted subsidiaries not included in income (3) — 17,500 Loss on extinguishment of debt (4) — 1,627 Differences in timing of cash receipts for certain contractual arrangements (5) 8,230 299 Change in provision for leased items no longer in use (431) 604 Redeemable noncontrolling interest redemption value adjustments (6) 7,823 4,791 Income tax expense 304 222 Total Segment Margin $ 157,452 $ 156,097 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The three months ended March 31, 2022 includes $6.2 million in unrealized gains from the valuation of our commodity derivative transactions (excluding fair value hedges) and an unrealized loss of $4.3 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three months ended March 31, 2021 includes an unrealized loss of $18.4 million from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. Refer to Note 1 5 and Note 16 for details. (3) The three months ended March 31, 2021 include $17.5 million in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. We received the principal payment associated with our previously owned NEJD pipeline in the fourth quarter of 2021. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility. (4) Refer to Note 9 for details surrounding the extinguishment of our 2023 Notes. (5) Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. (6) Includes PIK distributions attributable to the period and accretion on the redemption feature.

Transactions with Related Par_2

Transactions with Related Parties (Tables)	3 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
Schedule Of Transactions with Related Parties	The transactions with related parties were as follows: Three Months Ended 2022 2021 Revenues: Revenues from services and fees to Poseidon (1) $ 3,238 $ 3,786 Revenues from product sales to ANSAC 88,182 67,955 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon (1) 255 240 Charges for services from ANSAC 845 178 (1) We own a 64% interest in Poseidon. Receivables from and payables to ANSAC as of March 31, 2022 and December 31, 2021 are as follows: March 31, December 31, 2022 2021 Accounts receivable - trade, net: ANSAC $ 68,758 $ 64,799 Accounts payable - trade: ANSAC $ 845 $ 116

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2022
Supplemental Cash Flow Elements [Abstract]
Net Changes In Components of Operating Assets and Liabilities	The following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended 2022 2021 (Increase) decrease in: Accounts receivable $ (131,249) $ (99,504) Inventories (282) 27,450 Deferred charges 12,805 7,731 Other current assets (2,677) (2,294) Increase (decrease) in: Accounts payable 107,747 38,994 Accrued liabilities (15,513) 22,561 Net changes in components of operating assets and liabilities $ (29,169) $ (5,062)

Derivatives (Tables)

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments	At March 31, 2022, we had the following outstanding commodity derivative commodity contracts that were entered into to economically hedge inventory, fixed price purchase commitments or forecasted purchases. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 62 — Weighted average contract price per Bbl $ 103.28 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 Bbls) 54 51 Weighted average contract price per Bbl $ 107.63 $ 107.92 Natural gas swaps: Contract volumes (10,000 MMBtu) — 367 Weighted average price differential per MMBtu $ — $ 0.03 Natural gas futures: Contract volumes (10,000 MMBtu) 155 459 Weighted average contract price per MMBtu $ 4.91 $ 4.14 Natural gas options Contract volumes (10,000 MMBtu) 26 8 Weighted average premium received/paid $ 0.16 $ 0.03 Crude oil options: Contract volumes (1,000 Bbls) 8 — Weighted average premium received/paid $ 12.47 $ —
Schedule of Fair Value of Derivative Assets and Liabilities	The following tables reflect the estimated fair value position of our derivatives at March 31, 2022 and December 31, 2021: Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, 2021 Asset Derivatives: Natural Gas Swap (undesignated hedge) Current Assets - Other 300 1,867 Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 6,856 $ 310 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (837) (310) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ 6,019 $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized assets Current Assets - Other $ 688 $ 49 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (504) (49) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets $ 184 $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (87,468) (52,372) Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued Liabilities (946) (608) Commodity derivatives - futures and put and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (837) $ (2,380) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 837 2,380 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — Commodity derivatives - futures (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (504) $ (209) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 504 209 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets $ — $ — (1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under “Current Assets - Other”. (2) Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative.
Schedule of Effect on Operating Results	Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended 2022 2021 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (1,170) $ (5,897) Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs 6,048 (3,921) Total commodity derivatives $ 4,878 $ (9,818) Natural Gas Swap Sodium minerals and sulfur services operating costs $ (1,102) $ (67) Preferred Distribution Rate Reset Election Other expense $ (4,258) $ (18,438)

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2022
Fair Value Disclosures [Abstract]
Schedule of Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels	The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2022 and December 31, 2021. March 31, 2022 December 31, 2021 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 7,544 $ 300 $ — $ 359 $ 1,867 $ — Liabilities $ (1,341) $ (946) $ — $ (2,589) $ (608) $ — Preferred Distribution Rate Reset Election $ — $ — $ (87,468) $ — $ — $ (83,210)
Schedule of Reconciliation of Changes in Fair Value of Derivatives Classified as Level 3	The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3: Balance as of December 31, 2021 $ (83,210) Net loss for the period included in earnings (4,258) Balance as of March 31, 2022 $ (87,468)

Organization and Basis of Pre_2

Organization and Basis of Presentation and Consolidation (Details)	3 Months Ended
	Mar. 31, 2022segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregated Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Total revenues	$ 631,947	$ 521,219
Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	137,473	129,109
Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	467,575	369,601
Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	26,899	22,509
Offshore Pipeline Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	68,068	64,384
Offshore Pipeline Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	68,068	64,384
Offshore Pipeline Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Offshore Pipeline Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Sodium Minerals and Sulfur Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	285,674	227,287
Sodium Minerals and Sulfur Services [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Sodium Minerals and Sulfur Services [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	258,775	204,778
Sodium Minerals and Sulfur Services [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	26,899	22,509
Marine Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	55,774	40,331
Marine Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	55,774	40,331
Marine Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Marine Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Onshore Facilities and Transportation [Member]
Disaggregation of Revenue [Line Items]
Total revenues	222,431	189,217
Onshore Facilities and Transportation [Member] | Fee-based Revenues [Member]
Disaggregation of Revenue [Line Items]
Total revenues	13,631	24,394
Onshore Facilities and Transportation [Member] | Product Sales [Member]
Disaggregation of Revenue [Line Items]
Total revenues	208,800	164,823
Onshore Facilities and Transportation [Member] | Refinery Services [Member]
Disaggregation of Revenue [Line Items]
Total revenues	$ 0	$ 0

Revenue Recognition (Contract A

Revenue Recognition (Contract Assets and Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Revenue Recognition [Abstract]
Contract Assets, Current Assets-Other	$ 4,687	$ 13,563
Contract Liability, Accrued Liabilities	2,415	2,619
Contract Liabilities, Other Long-Term Liabilities	$ 18,498	$ 19,028

Revenue Recognition (Revenue Ex

Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in Thousands	Mar. 31, 2022USD ($)
Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 345,316
Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	14,400
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 55,635
Revenue expected timing of satisfaction period	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 5,400
Revenue expected timing of satisfaction period	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 65,645
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 7,200
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 59,034
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 1,800
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 62,699
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 44,691
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Offshore Pipeline Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 57,612
Revenue expected timing of satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | Onshore Facilities and Transportation [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods	$ 0
Revenue expected timing of satisfaction period

Lease Accounting (Details)

Lease Accounting (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Marine Transportation [Member] | M/T American Phoenix [Member]
Lessor, Lease, Description [Line Items]
Operating lease income	$ 4,100	$ 3,400

Inventories (Major Components o

Inventories (Major Components of Inventories) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Petroleum products	$ 795	$ 998
Crude oil	8,962	11,834
Caustic soda	6,654	5,690
NaHS	18,308	17,040
Raw materials - Alkali operations	7,760	7,599
Work-in-process - Alkali operations	10,058	7,496
Finished goods, net - Alkali operations	17,669	13,681
Materials and supplies, net - Alkali operations	13,888	13,620
Total	$ 84,094	$ 77,958

Inventories (Narrative) (Detail

Inventories (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2020
Inventory Disclosure [Abstract]
Inventory write-down	$ 0	$ 2

Fixed Assets, Mineral Leaseho_3

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Fixed Assets, Net) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 5,519,055	$ 5,464,040
Less: Accumulated depreciation	(1,607,285)	(1,551,855)
Net fixed assets	3,911,770	3,912,185
Crude oil and natural gas pipelines and related assets
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	2,840,622	2,839,443
Onshore facilities, machinery and equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	269,107	269,245
Onshore facilities, machinery and equipment | Alkali Business
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	675,940	670,880
Transportation equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	21,056	21,106
Marine vessels
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	1,018,919	1,018,284
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	228,450	227,540
Office equipment, furniture and fixtures
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	26,535	23,965
Construction in progress
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	400,840	350,137
Other
Property, Plant and Equipment [Line Items]
Fixed assets, at cost	$ 37,586	$ 43,440

Fixed Assets, Mineral Leaseho_4

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Mineral Leaseholds) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Mineral leaseholds	$ 566,019	$ 566,019
Less: Accumulated depletion	(18,034)	(17,014)
Mineral leaseholds, net of accumulated depletion	$ 547,985	$ 549,005

Fixed Assets, Mineral Leaseho_5

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 65,750	$ 62,702
Depletion expense	$ 1,020	$ 912

Fixed Assets, Mineral Leaseho_6

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Asset Retirement Obligation Rollforward) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2022USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2021	$ 220,906
Accretion expense	3,447
Settlements	(1,461)
ARO liability balance, March 31, 2022	$ 222,892

Fixed Assets, Mineral Leaseho_7

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 222,892	$ 220,906
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 35,300	$ 36,300

Fixed Assets, Mineral Leaseho_8

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Forecast of Accretion Expense) (Details) $ in Thousands	Mar. 31, 2022USD ($)
Fixed Assets And Asset Retirement Obligations [Abstract]
Remainder of 2022	$ 9,486
2023	10,583
2024	9,767
2025	10,469
2026	$ 8,216

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 316.3	$ 319.9

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Genesis’ share of operating earnings	$ 16,010	$ 24,533
Amortization of differences attributable to Genesis’ carrying value of equity investments	(3,566)	(3,873)
Net equity in earnings	12,444	20,660
Distributions received	$ 19,018	$ 29,516

Equity Investees (Schedule of B

Equity Investees (Schedule of Balance Sheet Information for Equity Investees) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Assets
Current assets	$ 669,599	$ 542,484
Fixed assets, net	3,911,770	3,912,185
Total assets	6,019,199	5,905,801
LIABILITIES AND CAPITAL
Current liabilities	597,205	496,939
Total liabilities and equity	6,019,199	5,905,801
Poseidon
Assets
Current assets	15,869	17,827
Fixed assets, net	156,464	160,379
Other assets	11,430	6,186
Total assets	183,763	184,392
LIABILITIES AND CAPITAL
Current liabilities	7,436	7,668
Other liabilities	233,066	231,970
Equity (Deficit)	(56,739)	(55,246)
Total liabilities and equity	$ 183,763	$ 184,392

Equity Investees (Schedule of O

Equity Investees (Schedule of Operations for Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
INCOME STATEMENT DATA:
Revenues	$ 631,947	$ 521,219
Operating income	51,671	28,021
Net income	(5,250)	(34,224)
Poseidon
INCOME STATEMENT DATA:
Revenues	31,189	42,413
Operating income	21,953	32,161
Net income	$ 20,907	$ 31,145

Intangible Assets (Schedule of

Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 199,141	$ 196,834
Accumulated Amortization	72,358	69,771
Carrying Value	126,783	127,063
Contract intangibles | Marine Transportation [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	800	800
Accumulated Amortization	616	607
Carrying Value	184	193
Contract intangibles | Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	158,101	158,101
Accumulated Amortization	55,474	53,394
Carrying Value	102,627	104,707
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	40,240	37,933
Accumulated Amortization	16,268	15,770
Carrying Value	$ 23,972	$ 22,163

Intangible Assets (Schedule o_2

Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Amortization of intangible assets	$ 2,588	$ 2,600
Remainder of 2021	8,988
2023	11,733
2024	11,368
2025	11,143
2026	$ 10,843

Debt (Schedule of Obligations U

Debt (Schedule of Obligations Under Debt Arrangements) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021	Dec. 17, 2020
Debt Instrument [Line Items]
Principal	$ 3,051,543	$ 3,005,743
Unamortized Premium and Debt Issuance Costs	24,740	26,238
Net Value	3,026,803	2,979,505
Credit Facility | Revolving Credit Facility | Revolving Loan
Debt Instrument [Line Items]
Principal	94,800	49,000
Unamortized Premium and Debt Issuance Costs	0	0
Net Value	94,800	49,000
Unamortized debt issuance costs	$ 4,200	$ 4,700
Senior Notes | 5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Interest rate	562.50%	562.50%
Principal	$ 341,135	$ 341,135
Unamortized Premium and Debt Issuance Costs	1,892	2,106
Net Value	$ 339,243	$ 339,029
Senior Notes | 6.500% senior unsecured notes due 2025
Debt Instrument [Line Items]
Interest rate	650.00%	650.00%
Principal	$ 534,834	$ 534,834
Unamortized Premium and Debt Issuance Costs	4,155	4,452
Net Value	$ 530,679	$ 530,382
Senior Notes | 6.250% senior unsecured notes due 2026
Debt Instrument [Line Items]
Interest rate	625.00%	625.00%
Principal	$ 359,799	$ 359,799
Unamortized Premium and Debt Issuance Costs	3,215	3,410
Net Value	$ 356,584	$ 356,389
Senior Notes | 8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Interest rate	800.00%	800.00%	8.00%
Principal	$ 1,000,000	$ 1,000,000
Unamortized Premium and Debt Issuance Costs	6,197	6,592
Net Value	$ 993,803	$ 993,408
Senior Notes | 7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Interest rate	775.00%	775.00%
Principal	$ 720,975	$ 720,975
Unamortized Premium and Debt Issuance Costs	9,281	9,678
Net Value	$ 711,694	$ 711,297

Debt (Narrative) (Details)

Debt (Narrative) (Details)	Nov. 16, 2021	Apr. 22, 2021USD ($)	Apr. 08, 2021USD ($)extension	Jan. 19, 2021USD ($)	Dec. 17, 2020USD ($)	Mar. 31, 2022USD ($)	Mar. 31, 2021USD ($)	Dec. 31, 2021
Debt Instrument [Line Items]
Repayment of senior unsecured notes						$ 0	$ 80,859,000
Loss on extinguishment of debt						$ 0	$ 1,627,000
Cameron Highway Oil Pipeline | Affiliated Entity
Debt Instrument [Line Items]
Sale Of Stock, Percentage Of Ownership Sold	0.36					0.36
Senior Notes | Guarantor Subsidiary | Genesis Energy, LLC | Genesis Finance Corporation
Debt Instrument [Line Items]
Guarantor obligations, current carrying value						$ 3,000,000,000
Percentage of equity interest						100.00%
Senior Secured Credit Facility | Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 950,000,000
Credit facility extension period			1 year
Credit facility, number of extensions | extension			2
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Letter of credit, fee percentage						3.25%
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Letter of credit, fee percentage						3.75%
Senior Secured Credit Facility | Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Letter of credit, fee percentage						2.25%
Revolving Loan | Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 650,000,000
Line of credit, unused capacity commitment fee percentage						0.50%
Credit facility, additional borrowing capacity						$ 200,000,000
Credit facility, amount borrowed						94,800,000
Letters of credit, outstanding amount						1,500,000
Line of Credit Facility, Remaining Borrowing Capacity						553,700,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount borrowed						$ 7,100,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage						0.50%
Letters of credit, outstanding amount						$ 100,000,000
Revolving Loan | Credit Facility | Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage						0.30%
Revolving Loan | Credit Facility | Revolving Credit Facility | Federal Funds Effective Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						0.50%
Revolving Loan | Credit Facility | Revolving Credit Facility | LIBOR Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						1.00%
Revolving Loan | Credit Facility | Revolving Credit Facility | Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						3.25%
Revolving Loan | Credit Facility | Revolving Credit Facility | Eurodollar Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						3.75%
Revolving Loan | Credit Facility | Revolving Credit Facility | Eurodollar Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						2.25%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						2.25%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						2.75%
Revolving Loan | Credit Facility | Revolving Credit Facility | Alternate Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						1.25%
Term Loan | Credit Facility
Debt Instrument [Line Items]
Debt Instrument, Face Amount						$ 300,000,000
8.000% senior unsecured notes due 2027 | Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000			$ 750,000,000
Interest rate					8.00%	800.00%		800.00%
Proceeds from issuance of debt					$ 737,000,000
Debt premium percentage		103.75%
6.000% senior unsecured notes due 2023 | Senior Notes
Debt Instrument [Line Items]
Interest rate					6.00%
Proceeds used to repay unsecured debt principal					$ 316,500,000
Repayment of senior unsecured notes				$ 80,900,000
Loss on extinguishment of debt						$ 1,600,000

Partners' Capital, Mezzanine _3

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

Partners' Capital, Mezzanine _4

Partners' Capital, Mezzanine Capital and Distributions (Narrative) (Details)	Nov. 17, 2021USD ($)	Nov. 16, 2021	Apr. 14, 2020USD ($)shares	Sep. 23, 2019USD ($)$ / sharesshares	Dec. 31, 2021shares	Mar. 31, 2022USD ($)shares	Mar. 31, 2021USD ($)
Temporary Equity [Line Items]
Common units outstanding (in units) | shares					122,579,218	122,579,218
Preferred units, accumulated distributions						$ 18,684,000	$ 18,684,000
Net Income (Loss) Attributable to Redeemable Noncontrolling Interest						7,823,000	4,791,000
Redemption accretion						$ 1,227,000
Cameron Highway Oil Pipeline | Affiliated Entity
Temporary Equity [Line Items]
Sale of Stock, Consideration Received on Transaction	$ 418,000,000
Sale of Stock, Percentage of Ownership after Transaction					64.00%
Sale Of Stock, Percentage Of Ownership Sold		0.36				0.36
Independence Hub, LLC | Affiliated Entity | Genesis Energy, LLC
Temporary Equity [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent						80.00%
Subsidiary | Alkali Holdings
Temporary Equity [Line Items]
Redeemable Noncontrolling Interest, Equity, Preferred, Purchase Price Per Unit | $ / shares				$ 1,000
Redeemable Noncontrolling Interest, Equity, Preferred, Units Issued, Value				$ 55,000,000
Redeemable noncontrolling interest preferred commitment				$ 350,000,000
Expansion project extension period			1 year
Equity preferred units issued (in units) | shares			1,750
Commitment period			4 years
Net Income (Loss) Attributable to Redeemable Noncontrolling Interest						$ 7,800,000	4,800,000
PIK distribution						6,600,000	4,100,000
Redemption accretion						1,200,000	700,000
Redemption value of redeemable preferred noncontrolling interest						$ 289,800,000
Period for occurrence of triggering events				6 years 6 months
Subsidiary | Alkali Holdings | Maximum
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares			351,750
Redeemable noncontrolling interest preferred commitment			$ 351,800,000
Subsidiary | Alkali Holdings | Minimum
Temporary Equity [Line Items]
Redeemable noncontrolling interest preferred commitment				$ 251,800,000
Common Class A | Limited Partner [Member]
Temporary Equity [Line Items]
Common units outstanding (in units) | shares						122,539,221
Common Class B | Limited Partner [Member]
Temporary Equity [Line Items]
Common units outstanding (in units) | shares						39,997
Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares					25,336,778	25,336,778
Preferred units, accumulated distributions						$ 18,700,000	$ 18,700,000
Redeemable Noncontrolling Interest Preferred Units
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares					246,394	250,114
Redeemable Noncontrolling Interest Preferred Units | Subsidiary | Alkali Holdings
Temporary Equity [Line Items]
Number of preferred units outstanding (in units) | shares				55,000		250,114

Partners' Capital, Mezzanine _5

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

Partners' Capital, Mezzanine _6

Partners' Capital, Mezzanine Capital and Distributions (Changes in Redeemable Noncontrolling Interests) (Details) - USD ($) $ in Thousands	Apr. 14, 2020	Mar. 31, 2022	Mar. 31, 2021
Redeemable Noncontrolling Interest, Equity [Roll Forward]
Balance as of December 31, 2021		$ 259,568
Redeemable Noncontrolling Interest, Equity, Preferred, Units issued value, net of issuance costs		3,646
Redeemable Noncontrolling Interest, Equity, Preferred, Distributions Paid-in-Kind		6,596
Redemption accretion		1,227
Tax distributions		(3,795)
Balance as of March 31, 2022		267,242
Subsidiary | Alkali Holdings
Redeemable Noncontrolling Interest, Equity [Roll Forward]
Redemption accretion		$ 1,200	$ 700
Redeemable Noncontrolling Interest [Line Items]
Equity preferred units issued to pay tax distributions (in units)		3,720
Equity preferred units issued (in units)	1,750

Net Loss Per Common Unit (Detai

Net Loss Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Earnings Per Share Reconciliation [Abstract]
Net loss attributable to Genesis Energy, L.P.	$ (5,250)	$ (34,224)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)	(18,684)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-BASIC	(23,934)	(52,908)
NET LOSS ATTRIBUTABLE TO COMMON UNITHOLDERS-DILUTED	$ (23,934)	$ (52,908)
Basic Weighted Average Outstanding Units (in units)	122,579,000	122,579,000
Dilutive Weighted Average Outstanding Units (in units)	122,579,000	122,579,000
Basic Net Loss per Common Unit (in dollars per unit)	$ (0.20)	$ (0.43)
Dilutive Net Loss per common unit (in dollars per unit)	$ (0.20)	$ (0.43)
Class A Convertible Preferred Stock Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities not included in computation of dilutive earnings (in units)	25,336,778

Business Segment Information (N

Business Segment Information (Narrative) (Details)	3 Months Ended
	Mar. 31, 2022segment
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
	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting Information [Line Items]
Segment margin	$ 157,452	$ 156,097
Total revenues	631,947	521,219
Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	68,068	64,384
Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total revenues	285,674	227,287
Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	222,431	189,217
Marine Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	55,774	40,331
Operating Segments
Segment Reporting Information [Line Items]
Segment margin	157,452	156,097
Capital expenditures	72,563	34,379
Total revenues	631,947	521,219
Operating Segments | Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	70,904	84,269
Capital expenditures	35,441	11,528
Total revenues	68,068	64,384
Operating Segments | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Segment margin	67,375	43,720
Capital expenditures	26,326	10,038
Total revenues	288,008	229,306
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	7,036	20,999
Capital expenditures	737	1,099
Total revenues	220,295	188,150
Operating Segments | Marine Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin	12,137	7,109
Capital expenditures	10,059	11,714
Total revenues	55,576	39,379
Intersegment
Segment Reporting Information [Line Items]
Total revenues	0	0
Intersegment | Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0
Intersegment | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total revenues	(2,334)	(2,019)
Intersegment | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	2,136	1,067
Intersegment | Marine Transportation [Member]
Segment Reporting Information [Line Items]
Total revenues	$ 198	$ 952

Business Segment Information _2

Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Total consolidated assets	$ 6,019,199	$ 5,905,801
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total consolidated assets	2,101,728	2,103,140
Operating Segments | Sodium Minerals and Sulfur Services [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	2,149,589	2,132,588
Operating Segments | Onshore Facilities and Transportation [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	1,014,005	923,064
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total consolidated assets	698,209	703,030
Other assets
Segment Reporting Information [Line Items]
Total consolidated assets	$ 55,668	$ 43,979

Business Segment Information (R

Business Segment Information (Reconciliation of Segment Margin to (Loss) Income from Continuing Operations) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Segment Reporting [Abstract]
Net loss attributable to Genesis Energy, L.P.	$ (5,250)	$ (34,224)
Corporate general and administrative expenses	15,721	11,152
Depreciation, depletion, amortization and accretion	72,948	68,997
Interest expense	55,104	57,829
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income	6,574	8,856
Other non-cash items	(3,571)	18,444
Distribution from unrestricted subsidiaries not included in income	0	(17,500)
Loss on extinguishment of debt	0	1,627
Differences in timing of cash receipts for certain contractual arrangements	8,230	299
Change in provision for leased items no longer in use	(431)	604
Redeemable noncontrolling interest redemption value adjustments	7,823	4,791
Income tax expense	304	222
Total Segment Margin	157,452	156,097
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives	1,903	(17,599)
Genesis NEJD Pipeline, LLC
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Cash receipts not included in income associated with principal payments of previously owned pipeline		17,500
Embedded Derivative Financial Instruments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives	4,300	$ (18,400)
Embedded Derivative Financial Instruments | Other Nonoperating Income (Expense)
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Amount of Gain (Loss) Recognized in Income	$ 6,200

Transactions with Related Par_3

Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - Affiliated Entity - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
CEO
Related Party Transaction [Line Items]
Costs and expenses	$ 165	$ 165
Poseidon
Related Party Transaction [Line Items]
Revenues	3,238	3,786
Costs and expenses	$ 255	240
Equity method investment, ownership percentage	64.00%
ANSAC
Related Party Transaction [Line Items]
Revenues	$ 88,182	67,955
Costs and expenses	$ 845	$ 178

Transactions with Related Par_4

Transactions with Related Parties (Narrative) (Details) - Affiliated Entity - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Poseidon
Related Party Transaction [Line Items]
Related party transaction, revenues	$ 3,238	$ 3,786
Due from related parties	1,300		$ 2,400
Related party transaction, costs and expenses	255	240
Poseidon | Asset Management Arrangement
Related Party Transaction [Line Items]
Related party transaction, revenues	2,400	2,400
ANSAC
Related Party Transaction [Line Items]
Related party transaction, revenues	88,182	67,955
Due from related parties	68,758		$ 64,799
Related party transaction, costs and expenses	$ 845	$ 178

Transactions with Related Par_5

Transactions with Related Parties (ANSAC) (Details) - ANSAC - Affiliated Entity - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Receivables	$ 68,758	$ 64,799
Payables	$ 845	$ 116

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
(Increase) decrease in:
Accounts receivable	$ (131,249)	$ (99,504)
Inventories	(282)	27,450
Deferred charges	12,805	7,731
Other current assets	(2,677)	(2,294)
Increase (decrease) in:
Accounts payable	107,747	38,994
Accrued liabilities	(15,513)	22,561
Net changes in components of operating assets and liabilities	$ (29,169)	$ (5,062)

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 69.8	$ 35.4
Interest paid, capitalized	2	0.7
Incurred liabilities for fixed and intangible asset additions	$ 45	$ 27.1

Derivatives (Schedule of Outsta

Derivatives (Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments) (Details) bbl in Thousands, MMBTU in Thousands	3 Months Ended
	Mar. 31, 2022MMBTU$ / bbl$ / MMBTUbbl
Designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	62
Weighted average contract price | $ / bbl	103.28
Designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	0
Weighted average contract price | $ / bbl	0
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	54
Weighted average contract price | $ / bbl	107.63
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	155
Weighted average contract price | $ / MMBTU	4.91
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	26
Weighted average contract price | $ / bbl	0.16
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 | Options | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	8
Weighted average premium received/paid | $ / bbl	12.47
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	51
Weighted average contract price | $ / bbl	107.92
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	459
Weighted average contract price | $ / MMBTU	4.14
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Fuel Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	8
Weighted average contract price | $ / bbl	0.03
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swaps | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU	367
Weighted average contract price | $ / MMBTU	0.03
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Options | Crude Oil
Derivative [Line Items]
Contract volumes (bbls) | bbl	0
Weighted average premium received/paid | $ / bbl	0

Derivatives (Schedule of Fair V

Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability	$ (87,500)
Preferred Distribution Rate Reset Election | Other long-term liabilities
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability	(87,468)	$ (52,372)
Not qualifying or not designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	6,856	310
Derivative Asset, Fair Value, Gross Liability	(837)	(310)
Asset Derivatives	6,019	0
Derivative Liability, Fair Value, Gross Liability	(837)	(2,380)
Derivative Liability, Fair Value, Gross Asset	837	2,380
Liability Derivatives	0	0
Not qualifying or not designated as hedges under accounting rules | Swaps | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	300	1,867
Not qualifying or not designated as hedges under accounting rules | Swaps | Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(946)	(608)
Designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	688	49
Derivative Asset, Fair Value, Gross Liability	(504)	(49)
Asset Derivatives	184	0
Derivative Liability, Fair Value, Gross Liability	(504)	(209)
Derivative Liability, Fair Value, Gross Asset	504	209
Liability Derivatives	$ 0	$ 0

Derivatives (Narrative) (Detail

Derivatives (Narrative) (Details)	Sep. 01, 2022	Mar. 31, 2022USD ($)	Dec. 31, 2021USD ($)
Derivatives, Fair Value [Line Items]
Net broker receivable		$ 3,800,000	$ 2,900,000
Initial margin		2,000,000	2,100,000
Variation margin		1,800,000	$ 800,000
Embedded derivative liability		$ 87,500,000
Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Period to notify holders	30 days
Stock reset rate percentage	10.75%
Percentage below issue price per share	110.00%
LIBOR | Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price	0.0750

Derivatives (Schedule of Effect

Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Commodity derivatives - futures and call options | Cost of Goods and Services Sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ 4,878	$ (9,818)
Natural Gas Swap | Cost of Goods and Services Sold | Sodium minerals and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(1,102)	(67)
Preferred Distribution Rate Reset Election | Other expense
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(4,258)	(18,438)
Contracts designated as hedges under accounting guidance | Commodity derivatives - futures and call options | Cost of Goods and Services Sold | Onshore facilities and transportation product costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(1,170)	(5,897)
Contracts not considered hedges under accounting guidance | Commodity derivatives - futures and call options | Cost of Goods and Services Sold | Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ 6,048	$ (3,921)

Fair-Value Measurements (Placem

Fair-Value Measurements (Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels) (Details) - Recurring Fair Value Measures - USD ($) $ in Thousands	Mar. 31, 2022	Dec. 31, 2021
Level 1 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 7,544	$ 359
Liabilities Fair Value	(1,341)	(2,589)
Level 1 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 2 | Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	300	1,867
Liabilities Fair Value	(946)	(608)
Level 2 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 3 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	0	0
Level 3 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	$ (87,468)	$ (83,210)

Fair-Value Measurements (Reconc

Fair-Value Measurements (Reconciliation of Changes in Derivatives Classified as Level 3) (Details) - Level 3 - Preferred Distribution Rate Reset Election $ in Thousands	3 Months Ended
	Mar. 31, 2022USD ($)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance as of December 31, 2021	$ (83,210)
Net loss for the period included in earnings	(4,258)
Balance as of March 31, 2022	$ (87,468)

Fair-Value Measurements (Narrat

Fair-Value Measurements (Narrative) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2022USD ($)	Mar. 31, 2021USD ($)	Dec. 31, 2021USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives	$ 1,903	$ (17,599)
Carrying value of senior unsecured notes	2,932,003		$ 2,930,505
Embedded Derivative Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (losses) gains from valuation of embedded derivatives	4,300	$ (18,400)
Carrying value of senior unsecured notes	3,000,000		3,000,000
Fair value of senior unsecured notes	$ 3,000,000		$ 3,000,000
Equity Volatility
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Embedded derivative liability, measurement input	0.50

Subsequent Events (Details)

Subsequent Events (Details) - USD ($)	Apr. 29, 2022	Mar. 31, 2022	Mar. 31, 2021
Subsequent Event [Line Items]
Payments to Noncontrolling Interests		$ 5,202,000	$ 0
Subsequent Event | Noncontrolling Interest [Member] | Independence Hub, LLC
Subsequent Event [Line Items]
Payments to Noncontrolling Interests	$ 8,000,000
Subsequent Event | Noncontrolling Interest [Member] | Independence Hub, LLC | Genesis Energy, LLC
Subsequent Event [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	20.00%
Subsequent Event | Independence Hub, LLC | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Proceeds from Sale of Productive Assets	$ 40,000,000