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GEL Genesis Energy

Cover

Cover - shares3 Months Ended
Mar. 31, 2021May 05, 2021
Entity Information [Line Items]
Document Type10-Q
Document Quarterly Reporttrue
Document Period End DateMar. 31,
2021
Document Transition Reportfalse
Entity File Number1-12295
Entity Registrant NameGENESIS ENERGY LP
Entity Incorporation, State or Country CodeDE
Entity Tax Identification Number76-0513049
Entity Address, Address Line One919 Milam, Suite 2100,
Entity Address, City or TownHouston
Entity Address, State or ProvinceTX
Entity Address, Postal Zip Code77002
City Area Code(713)
Local Phone Number860-2500
Title of 12(b) SecurityCommon units
Trading SymbolGEL
Security Exchange NameNYSE
Entity Current Reporting StatusYes
Entity Interactive Data CurrentYes
Entity Filer CategoryLarge Accelerated Filer
Entity Small Businessfalse
Entity Emerging Growth Companyfalse
Entity Shell Companyfalse
Entity Central Index Key0001022321
Current Fiscal Year End Date--12-31
Document Fiscal Year Focus2021
Document Fiscal Period FocusQ1
Amendment Flagfalse
Class A Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding122,539,221
Class B Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding39,997

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
CURRENT ASSETS:
Cash and cash equivalents $ 18,449 $ 21,282
Restricted cash15,338 5,736
Accounts receivable - trade, net473,929 392,465
Inventories72,427 99,877
Other64,000 60,809
Total current assets644,143 580,169
FIXED ASSETS, at cost5,206,508 5,173,475
Less: Accumulated depreciation(1,381,384)(1,322,141)
Net fixed assets3,825,124 3,851,334
MINERAL LEASEHOLDS, net of accumulated depletion551,663 552,575
EQUITY INVESTEES310,024 319,068
INTANGIBLE ASSETS, net of amortization127,848 128,742
GOODWILL301,959 301,959
RIGHT OF USE ASSETS, net149,711 153,925
OTHER ASSETS, net of amortization39,141 45,847
TOTAL ASSETS5,949,613 5,933,619
CURRENT LIABILITIES:
Accounts payable - trade257,728 198,433
Accrued liabilities196,366 184,978
Total current liabilities454,094 383,411
SENIOR SECURED CREDIT FACILITY699,000 643,700
SENIOR UNSECURED NOTES, net of debt issuance costs2,671,262 2,750,016
DEFERRED TAX LIABILITIES13,389 13,317
OTHER LONG-TERM LIABILITIES410,189 393,018
Total liabilities4,247,934 4,183,462
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at March 31, 2021 and December 31, 2020790,115 790,115
Redeemable noncontrolling interests, 161,209 and 141,249 preferred units issued and outstanding at March 31, 2021 and December 31, 2020, respectively163,655 141,194
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at March 31, 2021 and December 31, 2020758,031 829,326
Accumulated other comprehensive loss(9,243)(9,365)
Noncontrolling interests(879)(1,113)
Total partners' capital747,909 818,848
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL $ 5,949,613 $ 5,933,619

UNAUDITED CONDENSED CONSOLIDA_2

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - sharesMar. 31, 2021Dec. 31, 2020
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)161,209 141,249
Number of preferred units outstanding (in units)161,209 141,249

UNAUDITED CONDENSED CONSOLIDA_3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
REVENUES:
Total revenues $ 521,219 $ 539,923
COSTS AND EXPENSES:
General and administrative11,666 9,373
Depreciation, depletion and amortization66,286 74,357
Total costs and expenses493,198 480,761
OPERATING INCOME28,021 59,162
Equity in earnings of equity investees20,660 14,159
Interest expense(57,829)(54,965)
Other income (expense)(20,065)10,258
Income (loss) from operations before income taxes(29,213)28,614
Income tax (expense) benefit(222)365
NET INCOME (LOSS)(29,435)28,979
Net loss attributable to noncontrolling interests2 16
Net income attributable to redeemable noncontrolling interests(4,791)(4,086)
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.(34,224)24,909
Less: Accumulated distributions attributable to Class A Convertible Preferred Units(18,684)(18,684)
NET INCOME (LOSS) AVAILABLE TO COMMON UNITHOLDERS $ (52,908) $ 6,225
NET INCOME (LOSS) PER COMMON UNIT (Note 11):
Basic and Diluted (in dollars per unit) $ (0.43) $ 0.05
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted (in shares)122,579 122,579
Offshore pipeline transportation
REVENUES:
Total revenues $ 64,384 $ 78,429
COSTS AND EXPENSES:
Cost of products and services sold20,716 18,661
Sodium minerals and sulfur services
REVENUES:
Total revenues227,287 243,390
COSTS AND EXPENSES:
Cost of products and services sold184,431 205,233
Marine transportation
REVENUES:
Total revenues40,331 62,346
COSTS AND EXPENSES:
Cost of products and services sold33,086 42,937
Onshore facilities and transportation
REVENUES:
Total revenues189,217 155,758
Onshore facilities and transportation | Onshore facilities and transportation product costs
COSTS AND EXPENSES:
Cost of products and services sold160,751 111,952
Onshore facilities and transportation | Onshore facilities and transportation operating costs
COSTS AND EXPENSES:
Cost of products and services sold $ 16,262 $ 18,248

UNAUDITED CONDENSED CONSOLIDA_4

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income (loss) $ (29,435) $ 28,979
Other comprehensive income:
Amortization of prior service cost122 0
Total Comprehensive income (loss)(29,313)28,979
Comprehensive loss attributable to noncontrolling interests2 16
Comprehensive income attributable to redeemable noncontrolling interests(4,791)(4,086)
Comprehensive income (loss) attributable to Genesis Energy, L.P. $ (34,102) $ 24,909

UNAUDITED CONDENSED CONSOLIDA_5

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL - USD ($) shares in Thousands, $ in ThousandsTotalPartners’ CapitalPartners’ CapitalCommon UnitsNoncontrolling InterestAccumulated Other Comprehensive Loss
Partners' capital, beginning balance (in units) at Dec. 31, 2019122,579
Partners' capital, beginning balance at Dec. 31, 2019 $ 1,431,171 $ 1,443,320 $ (3,718) $ (8,431)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net loss24,893 24,909 (16)
Cash distributions to partners(67,419)(67,419)
Cash contributions from noncontrolling interests1,377 1,377
Amortization of prior service cost0
Distributions to Class A Convertible Preferred unitholders(18,684)(18,684)
Partners' capital, ending balance (in units) at Mar. 31, 2020122,579
Partners' capital, ending balance at Mar. 31, 20201,371,338 1,382,126 (2,357)(8,431)
Partners' capital, beginning balance (in units) at Dec. 31, 2020122,579
Partners' capital, beginning balance at Dec. 31, 2020818,848 829,326 (1,113)(9,365)
Increase (Decrease) in Partners' Capital [Roll Forward]
Net loss(34,226)(34,224)(2)
Cash distributions to partners(18,387)(18,387)
Cash contributions from noncontrolling interests236 236
Amortization of prior service cost122 122
Distributions to Class A Convertible Preferred unitholders(18,684)(18,684)
Partners' capital, ending balance (in units) at Mar. 31, 2021122,579
Partners' capital, ending balance at Mar. 31, 2021 $ 747,909 $ 758,031 $ (879) $ (9,243)

UNAUDITED CONDENSED CONSOLIDA_6

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ (29,435) $ 28,979
Adjustments to reconcile net income (loss) to net cash provided by operating activities -
Depreciation, depletion and amortization66,286 74,357
Amortization and write-off of debt issuance costs and discount3,210 11,527
Amortization of non-cash costs on previously owned direct financing leases0 (2,929)
Payments received under previously owned direct financing leases (Note 4)17,500 5,167
Equity in earnings of investments in equity investees(20,660)(14,159)
Cash distributions of earnings of equity investees19,929 13,505
Non-cash effect of long-term incentive compensation plans1,560 (5,027)
Deferred and other tax liabilities (benefits)72 (515)
Unrealized (gains) losses on derivative transactions17,599 (31,118)
Other, net6,160 2,231
Net changes in components of operating assets and liabilities (Note 14)(5,062)7,534
Net cash provided by operating activities77,159 89,552
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets(39,388)(38,001)
Cash distributions received from equity investees - return of investment9,314 7,060
Proceeds from asset sales23 61
Net cash used in investing activities(30,051)(30,880)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility212,000 393,500
Repayments on senior secured credit facility(156,700)(375,400)
Proceeds from issuance of senior unsecured notes due 20280 750,000
Proceeds from issuance of preferred units17,738 0
Repayment of senior unsecured notes(80,859)(750,000)
Debt issuance costs(1,916)(13,295)
Contributions from noncontrolling interests236 1,377
Distributions to common unitholders(18,387)(67,419)
Distributions to preferred unitholders(18,684)(18,684)
Other, net6,233 6,353
Net cash used in financing activities(40,339)(73,568)
Net increase (decrease) in cash, restricted cash, and cash equivalents6,769 (14,896)
Cash, restricted cash and cash equivalents at beginning of period27,018 56,405
Cash, restricted cash and cash equivalents at end of period $ 33,787 $ 41,509

Organization and Basis of Prese

Organization and Basis of Presentation and Consolidation3 Months Ended
Mar. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation and ConsolidationOrganization and Basis of Presentation and Consolidation Organization We are a growth-oriented master limited partnership formed 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 located primarily in the Gulf Coast region of the United States, Wyoming, and 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 and processing of crude oil and natural gas in the Gulf of Mexico; • Sodium minerals and sulfur services involving trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as the 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 the terminalling, blending, storing, marketing and transporting crude oil and petroleum products (primarily fuel oil, asphalt, and other heavy refined products); and • Marine transportation to provide waterborne transportation of petroleum products 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, 2020 (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. Covid-19 and Market Update In March 2020, the World Health Organization categorized Covid-19 as a pandemic, and the President of the United States declared the Covid-19 outbreak a national emergency. As further discussed in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations, the impact of the Covid-19 pandemic and the related economic, business and market disruptions continues to evolve and its future effects, including the severity and duration, remain uncertain. We continue to monitor the market environment and will evaluate whether any triggering events would indicate possible impairments of long-lived assets, intangible assets and goodwill. Management’s estimates are based on numerous assumptions about future operations and market conditions, which we believe to be reasonable but are inherently uncertain. The uncertainties underlying our assumptions and estimates could differ significantly from actual results, including with respect to the duration and severity of the Covid-19 pandemic. In the current volatile economic environment and to the extent conditions

Recent Accounting Developments

Recent Accounting Developments3 Months Ended
Mar. 31, 2021
Accounting Policies [Abstract]
Recent Accounting DevelopmentsRecent Accounting DevelopmentsRecently Adopted    During the first quarter of 2020, the SEC amended the financial disclosure requirements for guarantors and issuers of guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X to go in effect January 4, 2021. The amendment simplifies the disclosure requirements and permits the amended disclosures to be provided outside the footnotes in audited annual or unaudited interim consolidated financial statements in all filings. As permitted by the amendment, we have early adopted the amendment and included the required summarized financial information in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Revenue Recognition

Revenue Recognition3 Months Ended
Mar. 31, 2021
Revenue Recognition [Abstract]
Revenue RecognitionRevenue Recognition Revenue from Contracts with Customers The following tables reflect the disaggregation of our revenues by major category for the 2021 Quarter and the three months ended March 31, 2020 (the "2020 Quarter"), respectively: 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 Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities & Transportation Consolidated Fee-based revenues $ 78,429 $ — $ 62,346 $ 40,990 $ 181,765 Product Sales — 215,366 — 114,768 330,134 Refinery Services — 28,024 — — 28,024 $ 78,429 $ 243,390 $ 62,346 $ 155,758 $ 539,923 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, 2020 and March 31, 2021: Contract Assets Contract Liabilities Current Non-Current Current Non-Current Balance at December 31, 2020 $ 36,500 $ 12,065 $ 2,988 $ 19,834 Balance at March 31, 2021 35,930 3,174 2,849 19,187 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, 2021. We are exempted 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 2021 $ 48,198 $ 14,369 2022 75,623 4,703 2023 63,982 — 2024 56,326 — 2025 60,311 — Thereafter 97,761 — Total $ 402,201 $ 19,072

Lease Accounting

Lease Accounting3 Months Ended
Mar. 31, 2021
Leases [Abstract]
Lease AccountingLease Accounting Lessee Arrangements We lease a variety of transportation equipment (including trucks, trailers, and 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 asset and associated lease liability. Leases with a term of less than 12 months are not recorded on our Unaudited Condensed Consolidated Balance Sheets. Lease expenses are recognized 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 remaining provision for 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 2021 Quarter and 2020 Quarter, we acted as a lessor in revenue contracts associated with the M/T American Phoenix, which is included in our marine transportation segment. During the 2020 Quarter, we acted as a lessor in our Free State pipeline system, which is included in our onshore facilities and transportation segment. These revenues are recorded within their respective segment's revenues in the Unaudited Condensed Consolidated Statements of Operations. Our lease revenues for these arrangements (inclusive of fixed and variable consideration) are reflected in the table below: Three Months Ended 2021 2020 M/T American Phoenix $ 3,420 $ 6,643 Free State Pipeline (1) — 1,923 (1) We sold the Free State pipeline to a subsidiary of Denbury, Inc. ("Denbury") on October 30, 2020. Direct Finance Lease We formerly held a direct finance lease of the Northeast Jackson Dome ("NEJD") Pipeline. Under the terms of the finance lease, we were paid a quarterly payment, which commenced in August 3, 2008. During the third quarter of 2020, our customer, Denbury, defaulted under the agreement. On October 30, 2020 we executed an agreement with our customer to accelerate the remaining principal payments on the previously owned NEJD direct financing lease, payable in four equal installments. During the period ending March 31, 2021, we collected $17.5 million and we have an outstanding receivable (included within "Accounts receivable- trade, net" on the Unaudited Condensed Consolidated Balance Sheets) of $52.5 million as of March 31, 2021 from Denbury for the remaining payments due in 2021 per the agreement. Additionally as part of this transaction, we transferred the ownership of all of our CO2 assets to Denbury, including the Free State pipeline system as noted previously.
Lease AccountingLease Accounting Lessee Arrangements We lease a variety of transportation equipment (including trucks, trailers, and 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 asset and associated lease liability. Leases with a term of less than 12 months are not recorded on our Unaudited Condensed Consolidated Balance Sheets. Lease expenses are recognized 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 remaining provision for 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 2021 Quarter and 2020 Quarter, we acted as a lessor in revenue contracts associated with the M/T American Phoenix, which is included in our marine transportation segment. During the 2020 Quarter, we acted as a lessor in our Free State pipeline system, which is included in our onshore facilities and transportation segment. These revenues are recorded within their respective segment's revenues in the Unaudited Condensed Consolidated Statements of Operations. Our lease revenues for these arrangements (inclusive of fixed and variable consideration) are reflected in the table below: Three Months Ended 2021 2020 M/T American Phoenix $ 3,420 $ 6,643 Free State Pipeline (1) — 1,923 (1) We sold the Free State pipeline to a subsidiary of Denbury, Inc. ("Denbury") on October 30, 2020. Direct Finance Lease We formerly held a direct finance lease of the Northeast Jackson Dome ("NEJD") Pipeline. Under the terms of the finance lease, we were paid a quarterly payment, which commenced in August 3, 2008. During the third quarter of 2020, our customer, Denbury, defaulted under the agreement. On October 30, 2020 we executed an agreement with our customer to accelerate the remaining principal payments on the previously owned NEJD direct financing lease, payable in four equal installments. During the period ending March 31, 2021, we collected $17.5 million and we have an outstanding receivable (included within "Accounts receivable- trade, net" on the Unaudited Condensed Consolidated Balance Sheets) of $52.5 million as of March 31, 2021 from Denbury for the remaining payments due in 2021 per the agreement. Additionally as part of this transaction, we transferred the ownership of all of our CO2 assets to Denbury, including the Free State pipeline system as noted previously.

Inventories

Inventories3 Months Ended
Mar. 31, 2021
Inventory Disclosure [Abstract]
InventoriesInventories The major components of inventories were as follows: March 31, December 31, 2020 Petroleum products $ 2,584 $ 5,840 Crude oil 14,633 37,661 Caustic soda 5,108 5,167 NaHS 7,736 9,101 Raw materials - Alkali operations 6,492 7,120 Work-in-process - Alkali operations 10,700 9,355 Finished goods, net - Alkali operations 11,988 13,002 Materials and supplies, net - Alkali operations 13,186 12,631 Total $ 72,427 $ 99,877 Inventories are valued at the lower of cost or net realizable value. The net realizable value of inventories were recorded below cost by $0.4 million and $5.0 million as of March 31, 2021 and December 31, 2020, respectively, therefore we reduced the value of our inventory in our Unaudited Consolidated Financial Statements by these amounts. Materials and supplies include chemicals, maintenance supplies, and spare parts which will be consumed in the mining of trona ore and production of soda ash processes.

Fixed Assets, Mineral Leasehold

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations3 Months Ended
Mar. 31, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Fixed Assets, Mineral Leaseholds, and Asset Retirement ObligationsFixed Assets, Mineral Leaseholds, and Asset Retirement Obligations Fixed Assets Fixed assets, net consisted of the following: March 31, 2021 December 31, 2020 Crude oil pipelines and natural gas pipelines and related assets $ 2,810,931 $ 2,811,030 Alkali facilities, machinery, and equipment 635,446 622,598 Onshore facilities, machinery, and equipment 268,571 267,810 Transportation equipment 19,520 19,470 Marine vessels 1,002,601 998,553 Land, buildings and improvements 220,454 219,382 Office equipment, furniture and fixtures 22,096 22,001 Construction in progress 183,628 170,740 Other 43,261 41,891 Fixed assets, at cost 5,206,508 5,173,475 Less: Accumulated depreciation (1,381,384) (1,322,141) Net fixed assets $ 3,825,124 $ 3,851,334 Mineral Leaseholds Our Mineral Leaseholds, relating to our Alkali Business, consist of the following: March 31, December 31, 2020 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (14,356) (13,444) Mineral leaseholds, net of accumulated depletion $ 551,663 $ 552,575 Our depreciation and depletion expense for the periods presented was as follows: Three Months Ended March 31, 2021 2020 Depreciation expense $ 62,702 $ 69,242 Depletion expense 912 963 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, 2020: ARO liability balance, December 31, 2020 $ 176,852 Accretion expense 2,584 Changes in estimate 797 Settlements (2,017) ARO liability balance, March 31, 2021 $ 178,216 Of the ARO balances disclosed above, $13.6 million and $14.7 million is included as current in "Accrued liabilities" on our Unaudited Condensed Consolidated Balance Sheet as of March 31, 2021 and December 31, 2020, respectively. The remainder of the ARO liability as of March 31, 2021 and December 31, 2020 is included in "Other long-term liabilities" on our Unaudited Condensed Consolidated Balance Sheets. With respect to our AROs, the following table presents our estimate of accretion expense for the periods indicated: Remainder of 2021 $ 7,532 2022 $ 9,384 2023 $ 9,128 2024 $ 9,783 2025 $ 10,487 Certain of our unconsolidated affiliates have AROs recorded at March 31, 2021 relating to contractual agreements and regulatory requirements. These amounts are immaterial to our Unaudited Condensed Consolidated Financial Statements.

Equity Investees

Equity Investees3 Months Ended
Mar. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Equity InvesteesEquity 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, 2021 and December 31, 2020, the unamortized excess cost amounts totaled $331.5 million and $335.4 million, respectively. We amortize the excess cost as a reduction in equity earnings. The following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees: Three Months Ended March 31, 2021 2020 Genesis’ share of operating earnings $ 24,533 $ 18,032 Amortization of excess purchase price (3,873) (3,873) Net equity in earnings $ 20,660 $ 14,159 Distributions received $ 29,516 $ 20,565 The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. ("Poseidon") (which is our most significant equity investment): March 31, December 31, 2020 BALANCE SHEET DATA: Assets Current assets $ 17,531 $ 30,465 Fixed assets, net 168,723 171,732 Other assets 5,036 4,673 Total assets $ 191,290 $ 206,870 Liabilities and equity Current liabilities $ 11,720 $ 9,958 Other liabilities 229,008 237,595 Equity (49,438) (40,683) Total liabilities and equity $ 191,290 $ 206,870 Three Months Ended March 31, 2021 2020 INCOME STATEMENT DATA: Revenues $ 42,413 $ 32,892 Operating income $ 32,161 $ 23,606 Net income $ 31,145 $ 21,583 Poseidon's Revolving Credit Facility

Intangible Assets

Intangible Assets3 Months Ended
Mar. 31, 2021
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible AssetsIntangible Assets The following table summarizes the components of our intangible assets at the dates indicated: March 31, 2021 December 31, 2020 Gross Accumulated Carrying Gross Accumulated Carrying Marine contract intangibles $ 800 $ 580 $ 220 $ 800 $ 571 $ 229 Offshore pipeline contract intangibles 158,101 47,153 110,948 158,101 45,073 113,028 Other 30,949 14,269 16,680 29,244 13,759 15,485 Total $ 189,850 $ 62,002 $ 127,848 $ 188,145 $ 59,403 $ 128,742 Our amortization of intangible assets for the periods presented was as follows: Three Months Ended March 31, 2021 2020 Amortization of intangible assets $ 2,600 $ 4,116 We estimate that our amortization expense for the next five years will be as follows: Remainder of 2021 $ 8,323 2022 $ 10,973 2023 $ 10,705 2024 $ 10,390 2025 $ 10,222

Debt

Debt3 Months Ended
Mar. 31, 2021
Debt Disclosure [Abstract]
DebtDebt Our obligations under debt arrangements consisted of the following: March 31, 2021 December 31, 2020 Principal Unamortized Debt Issuance Costs (1) Net Value Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Senior secured credit facility $ 699,000 $ — $ 699,000 $ 643,700 $ — $ 643,700 6.000% senior unsecured notes due 2023 — — — 80,859 504 80,355 5.625% senior unsecured notes due 2024 341,135 2,749 338,386 341,135 2,963 338,172 6.500% senior unsecured notes due 2025 534,834 5,343 529,491 534,834 5,639 529,195 6.250% senior unsecured notes due 2026 359,799 3,994 355,805 359,799 4,189 355,610 8.000% senior unsecured notes due 2027 750,000 12,524 737,476 750,000 13,022 736,978 7.750% senior unsecured notes due 2028 720,975 10,871 710,104 720,975 11,269 709,706 Total long-term debt $ 3,405,743 $ 35,481 $ 3,370,262 $ 3,431,302 $ 37,586 $ 3,393,716 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in Other Long Term Assets on the Unaudited Condensed Consolidated Balance Sheets) were $4.8 million and $5.8 million as of March 31, 2021 and December 31, 2020, respectively. As of March 31, 2021, we were in compliance with the financial covenants contained in our credit agreement and senior unsecured notes indentures. Senior Secured Credit Facility At March 31, 2021, the key terms for rates under our $1.7 billion senior secured credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows: • The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate is equal to the sum of (a) the greatest of (i) the prime rate as established by the administrative agent for the credit facility, (ii) the federal funds effective rate plus 0.5% of 1% and (iii) the LIBOR rate for a one-month maturity 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 1.75% to 3.50% on Eurodollar borrowings and from 0.75% to 2.50% on alternate base rate borrowings, depending on our leverage ratio. Our leverage ratio is recalculated quarterly and in connection with each material acquisition. At March 31, 2021, the applicable margins on our borrowings were 2.50% for alternate base rate borrowings and 3.50% for Eurodollar rate borrowings. • Letter of credit fee rates range from 1.75% to 3.50% based on our leverage ratio as computed under the credit facility. The rate can fluctuate quarterly. At March 31, 2021, our letter of credit rate was 3.50%. • We pay a commitment fee on the unused portion of the $1.7 billion maximum facility amount. The commitment fee rates on the unused committed amount will range from 0.25% to 0.50% per annum depending on our leverage ratio. At March 31, 2021, our commitment fee rate on the unused committed amount was 0.50%. • The accordion feature is $300.0 million, giving us the ability to expand the size of the facility to up to $2.0 billion for acquisitions or growth projects, subject to lender consent. At March 31, 2021, we had $699.0 million borrowed under our $1.7 billion credit facility, with $13.0 million of the borrowed amount designated as a loan under the inventory sublimit. Our credit agreement allows up to $200.0 million of the capacity to be used for letters of credit, of which $1.3 million was outstanding at March 31, 2021. Due to the revolving nature of loans under our credit facility, additional borrowings and periodic repayments and re-borrowings may be made until the maturity date. The total amount available for borrowings under our existing credit facility at March 31, 2021 was $999.7 million, subject to compliance with covenants. On April 8, 2021, we entered into an amended and restated credit facility agreement to, among other things, extend the term of our existing credit facility. Refer to Note 18 for additional details. As a general rule, the assets and credit of our unrestricted subsidiaries are not available to satisfy the debts of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries (as defined below in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations), and the liabilities of our unrestricted subsidiaries do not constitute obligations of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries except, in the case of Genesis Alkali Holdings Company, LLC ("Alkali Holdings") and Genesis Energy, L.P., to the extent agreed to in the services agreement between Genesis Energy, L.P. and Alkali Holdings dated as of September 23, 2019 (the "Services Agreement"). Senior Unsecured Note Transactions On January 16, 2020, we issued $750 million in aggregate principal amount of our 7.75% senior unsecured notes due February 15, 2028 (the “2028 Notes”). Interest payments are due February 1 and August 1 of each year. That issuance generated net proceeds of $736.7 million, net of issuance costs incurred. We used $554.8 million of the net proceeds to redeem a portion of the 6.75% senior unsecured notes due August 1, 2022 (the "2022 Notes"), including principal, accrued interest and tender premium that were validly tendered, and the remaining net proceeds were used to repay a portion of the borrowings outstanding under our revolving credit facility. On January 17, 2020 we called for redemption the remaining $222.1 million of our 2022 Notes, and they were redeemed on February 16, 2020. We incurred a total loss of approximately $23.5 million relating to the extinguishment of our 2022 senior unsecured notes, inclusive of our transactions costs and the write-off of the related unamortized debt issuance costs and discount, which is recorded in "Other income (expense)" in our Unaudited Condensed Consolidated Statements of Operations for the 2020 Quarter. 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 at the time 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 senior unsecured notes, inclusive of the redemption fee and the write-off of the related unamortized debt issuance costs, which is recorded in "Other income (expense)" in our Unaudited Condensed Consolidated Statements of Operations for the 2021 Quarter. On April 22, 2021 we completed our offering of an additional $250 million in aggregate principal amount of the 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 we issued on December 17, 2020. The $250 million of the 2027 Notes were issued at a premium of 103.75% plus accrued interest from December 17, 2020. Refer to Note 18

Partners' Capital, Mezzanine Ca

Partners' Capital, Mezzanine Capital and Distributions3 Months Ended
Mar. 31, 2021
Equity [Abstract]
Partners' Capital, Mezzanine Capital and DistributionsPartners’ Capital, Mezzanine Capital and Distributions At March 31, 2021, our outstanding common units consisted of 122,539,221 Class A units and 39,997 Class B units. Distributions We paid or will pay the following distributions to our common unitholders in 2020 and 2021: Distribution For Date Paid Per Unit Total 2020 1 st Quarter May 15, 2020 $ 0.15 $ 18,387 2 nd Quarter August 14, 2020 $ 0.15 $ 18,387 3 rd Quarter November 13, 2020 $ 0.15 $ 18,387 4 th Quarter February 12, 2021 $ 0.15 $ 18,387 2021 1 st Quarter May 14, 2021 (1) $ 0.15 $ 18,387 (1) This distribution was declared on April 7, 2021 and will be paid to unitholders of record as of April 30, 2021. Class A Convertible Preferred Units At March 31, 2021 we had 25,336,778 Class A Convertible Preferred Units (our "Class A Convertible Preferred Units") outstanding. Our Class A Convertible Preferred Units rank senior to all of our currently outstanding classes or series of limited partner interests with respect to distribution and/or liquidation rights. Holders of our Class A Convertible Preferred Units vote on an as-converted basis with holders of our common units and have certain class voting rights, including with respect to any amendment to the partnership agreement that would adversely affect the rights, preferences or privileges, or otherwise modify the terms, of those Class A Convertible Preferred Units. Accounting for the Class A Convertible Preferred Units Our Class A Convertible Preferred Units are considered redeemable securities under GAAP due to the existence of redemption provisions upon a deemed liquidation event that is outside our control. Therefore, we present them as temporary equity in the mezzanine section of the Unaudited Condensed Consolidated Balance Sheets. Because our Class A Convertible Preferred Units are not currently redeemable and we do not have plans or expect any events that constitute a change of control in our partnership agreement, we present our Class A Convertible Preferred Units at their initial carrying amount. However, we would be required to adjust that carrying amount if it becomes probable that we would be required to redeem our Class A Convertible Preferred Units. Initial and Subsequent Measurement We initially recognized our Class A Convertible Preferred Units at their issuance date fair value, net of issuance costs. We will not be required to adjust the carrying amount of our Class A Convertible Preferred Units until it becomes probable that they would become redeemable. Once redemption becomes probable, we would adjust the carrying amount of our Class A Convertible Preferred Units to the redemption value over a period of time comprising the date the feature first becomes probable and the date the units can first be redeemed. Our Class A Convertible Preferred Units contain a distribution Rate Reset Election (as defined in Note 15 ). This Rate Reset Election is bifurcated and accounted for separately as an embedded derivative and recorded at fair value at each reporting period. Refer to Note 15 and Note 16 for additional discussion. Net Income (Loss) Attributable to Genesis Energy, L.P. is reduced by Class A Convertible Preferred Unit distributions that accumulated during the period. Net Income (Loss) Attributable to Genesis Energy, L.P. was reduced by $18.7 million for the 2021 Quarter and 2020 Quarter. We paid or will pay the following cash distributions to our Class A Convertible Preferred unitholders in 2020 and 2021: Distribution For Date Paid Per Unit Total 2020 1 st Quarter May 15, 2020 $ 0.7374 $ 18,684 2 nd Quarter August 14, 2020 $ 0.7374 $ 18,684 3 rd Quarter November 13, 2020 $ 0.7374 $ 18,684 4 th Quarter February 12, 2021 $ 0.7374 $ 18,684 2021 1 st Quarter May 14, 2021 (1) $ 0.7374 $ 18,684 (1) This distribution was declared on April 7, 2021 and will be paid to unitholders of record as of April 30, 2021. 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 GSO Capital Partners LP (collectively "GSO") purchased $55,000,000 (or 55,000 Alkali Holdings preferred units) and committed to purchase up to $350,000,000 of preferred units in Alkali Holdings, the entity that holds our trona and trona-based exploring, mining, processing, producing, marketing and selling business, including its Granger facility near Green River, Wyoming. Alkali Holdings will use the net proceeds from the Alkali Holdings preferred units to fund up to 100% of the anticipated cost of expansion of the Granger facility. On April 14, 2020, we entered into an amendment to our agreements with GSO to, among other things, extend the construction timeline of the Granger expansion project by one year, which we currently anticipate completing near the end of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to GSO, which was accounted for as issuance costs. As part of the amendment, the commitment period was increased to four years, and the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. As of March 31, 2021, there are 161,209 Alkali Holdings preferred units outstanding. 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, 2021 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 Income (Loss) Attributable to Genesis Energy, L.P. for the 2021 Quarter includes $4.8 million of adjustments, of which $4.1 million was allocated to the paid-in-kind ("PIK") distributions on the outstanding Alkali Holdings preferred units and $0.7 million was attributable to redemption accretion value adjustments. Net Income (Loss) Attributable to Genesis Energy, L.P. for the 2020 Quarter includes $4.1 million of adjustments, of which $3.3 million was allocated to the PIK distributions and $0.8 million was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended March 31, 2021 in-kind to our Alkali Holdings preferred unitholders. The unitholders liquidation preference is increased by new issuances and these 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, 2021, the redemption amount would be equal to $212.9 million, which would be the multiple of invested capital metric applied to the Alkali Holdings preferred units outstanding plus the make-whole amount on the undrawn minimum Alkali Holdings preferred units. The following table shows the change in our redeemable noncontrolling interest balance from December 31, 2020 to March 31, 2021: Balance as of December 31, 2020 $ 141,194 Issuance of preferred units, net of issuance costs (1) 19,561 PIK distribution 4,093 Redemption accretion 698 Tax distributions (1) (1,891) Balance as of March 31, 2021 $ 163,655

Net Income (Loss) Per Common Un

Net Income (Loss) Per Common Unit3 Months Ended
Mar. 31, 2021
Net Income per Common Unit [Abstract]
Net Income (Loss) Per Common UnitNet Income (Loss) Per Common Unit Basic net income per common unit is computed by dividing net income, after considering income attributable to our preferred unitholders, by the weighted average number of common units outstanding. The dilutive effect of our Class A Convertible Preferred Units is calculated using the if-converted method. Under the if-converted method, these units 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 2021 Quarter, the effect of the assumed conversion of the 25,336,778 Class A Convertible Preferred Units was anti-dilutive and was not included in the computation of diluted earnings per unit. The following table reconciles net income (loss) and weighted average units used in computing basic and diluted net income (loss) per common unit (in thousands, except per unit amounts): Three Months Ended 2021 2020 Net Income (Loss) Attributable to Genesis Energy L.P. $ (34,224) $ 24,909 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (18,684) (18,684) Net Income (Loss) Available to Common Unitholders $ (52,908) $ 6,225 Weighted Average Outstanding Units 122,579 122,579 Basic and Diluted Net Income (Loss) per Common Unit $ (0.43) $ 0.05

Business Segment Information

Business Segment Information3 Months Ended
Mar. 31, 2021
Segment Reporting [Abstract]
Business Segment InformationBusiness 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 selling 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, 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 the 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, 2021 Segment Margin (a) $ 84,269 $ 43,720 $ 20,999 $ 7,109 $ 156,097 Capital expenditures (b) $ 11,528 $ 10,038 $ 1,099 $ 11,714 $ 34,379 Revenues: External customers $ 64,384 $ 229,306 $ 188,150 $ 39,379 $ 521,219 Intersegment (c) — (2,019) 1,067 952 $ — Total revenues of reportable segments $ 64,384 $ 227,287 $ 189,217 $ 40,331 $ 521,219 Three Months Ended March 31, 2020 Segment Margin (a) $ 85,246 $ 36,941 $ 28,099 $ 19,002 $ 169,288 Capital expenditures (b) $ 1,027 $ 14,975 $ 1,157 $ 14,232 $ 31,391 Revenues: External customers $ 78,429 $ 245,535 $ 156,799 $ 59,160 $ 539,923 Intersegment (c) — (2,145) (1,041) 3,186 $ — Total revenues of reportable segments $ 78,429 $ 243,390 $ 155,758 $ 62,346 $ 539,923 (a) A reconciliation of total Segment Margin to net income (loss) attributable to Genesis Energy, L.P. for the periods is presented below. (b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as contributions to equity investees, if any. (c) 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, 2020 Offshore pipeline transportation $ 2,169,156 $ 2,187,083 Sodium minerals and sulfur services 1,958,893 1,962,146 Onshore facilities and transportation 1,065,316 1,035,662 Marine transportation 715,404 711,058 Other assets 40,844 37,670 Total consolidated assets $ 5,949,613 $ 5,933,619 Reconciliation of total Segment Margin to net income (loss) attributable to Genesis Energy, L.P.: Three Months Ended March 31, 2021 2020 Total Segment Margin $ 156,097 $ 169,288 Corporate general and administrative expenses (11,152) (6,492) Depreciation, depletion, amortization and accretion (68,997) (75,978) Interest expense (57,829) (54,965) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (8,856) (6,406) Other non-cash items (2) (18,444) 33,261 Distribution from unrestricted subsidiaries not included in income (3) (17,500) (2,238) Loss on extinguishment of debt (4) (1,627) (23,480) Differences in timing of cash receipts for certain contractual arrangements (5) (299) (4,490) Provision for leased items no longer in use (604) 130 Redeemable noncontrolling interest redemption value adjustments (6) (4,791) (4,086) Income tax (expense) benefit (222) 365 Net income (loss) attributable to Genesis Energy, L.P. $ (34,224) $ 24,909 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The 2021 Quarter and 2020 Quarter include a $18.4 million unrealized loss and $32.5 million unrealized gain, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. Refer to Note 16 for details. (3) The 2021 Quarter and 2020 Quarter include $17.5 million and $2.2 million, respectively, in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility. See N ote 4 for details. (4) The 2021 Quarter includes the transaction costs and write-off of the unamortized issuance costs associated with the redemption of our remaining 2023 Notes. The 2020 Quarter includes the transaction costs associated with the tender and redemption of our 2022 Notes, along with the write-off of the unamortized issuance costs and discount associated with these notes. Refer to Note 9 for details. (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 Parties3 Months Ended
Mar. 31, 2021
Related Party Transactions [Abstract]
Transactions with Related PartiesTransactions with Related Parties The transactions with related parties were as follows: Three Months Ended March 31, 2021 2020 Revenues: Revenues from services and fees to Poseidon (1) $ 3,786 $ 3,147 Revenues from product sales to ANSAC 67,955 73,079 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon (1) 240 254 Charges for services from ANSAC 178 832 (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. Poseidon We are the operator of Poseidon and provide management, administrative and pipeline operator services to Poseidon under an Operation and Management Agreement. Currently, that agreement renews automatically annually unless terminated by either party (as defined in the agreement). Our revenues for the 2021 Quarter and 2020 Quarter reflect $2.4 million and $2.3 million, respectively, of fees we earned through the provision of services under that agreement. At March 31, 2021 and December 31, 2020, Poseidon owed us $1.5 million and $2.6 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, 2021, such amount is not material to us. Net Sales to ANSAC were $68.0 million during the 2021 Quarter and were $73.1 million during the 2020 Quarter. The costs charged to us by ANSAC, included in operating costs, were $0.2 million during the 2021 Quarter and were $0.8 million during the 2020 Quarter. Receivables from and payables to ANSAC as of March 31, 2021 and December 31, 2020 are as follows: March 31, December 31, 2021 2020 Receivables: ANSAC $ 52,972 $ 43,400 Payables: ANSAC $ 349 $ 470

Supplemental Cash Flow Informat

Supplemental Cash Flow Information3 Months Ended
Mar. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow InformationSupplemental Cash Flow Information The following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended March 31, 2021 2020 (Increase) decrease in: Accounts receivable $ (99,504) $ 101,405 Inventories 27,450 (5,024) Deferred charges 7,731 2,783 Other current assets (2,294) (3,746) Increase (decrease) in: Accounts payable 38,994 (62,365) Accrued liabilities 22,561 (25,519) Net changes in components of operating assets and liabilities $ (5,062) $ 7,534 Payments of interest and commitment fees were $35.4 million and $33.7 million for the 2021 Quarter and 2020 Quarter, respectively. We capitalized interest of $0.7 million and $0.5 million during the 2021 Quarter and 2020 Quarter, respectively.

Derivatives

Derivatives3 Months Ended
Mar. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DerivativesDerivatives Commodity Derivatives We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (primarily futures and options contracts traded on the NYMEX) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil and petroleum products. Our decision as 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 derivative contracts available on the NYMEX; therefore, we do not designate derivative contracts utilized to limit our price risk related to these 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 in the Unaudited Condensed Consolidated Statements of Operations. In accordance with NYMEX requirements, we fund the margin associated with our commodity derivative contracts traded on the NYMEX. The amount of the margin is adjusted daily based on the fair value of the commodity contracts. The margin requirements are intended to mitigate a party's exposure to market volatility and the associated contracting party risk. We offset fair value amounts recorded for our NYMEX derivative contracts against margin funding as required by the NYMEX in Current Assets - Other in our Unaudited Condensed Consolidated Balance Sheets. Additionally, we enter into swap arrangements. Our Alkali Business relies on natural gas to generate heat and electricity for operations. We use a combination of commodity price swap contracts and future purchase contracts to manage our exposure to fluctuations in natural gas prices. The swap contracts fix the basis differential between NYMEX Henry Hub and NW Rocky Mountain posted prices. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. At March 31, 2021, we entered into the following outstanding derivative commodity contracts to economically hedge inventory or fixed price purchase commitments. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 92 — Weighted average contract price per bbl $ 56.75 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 411 318 Weighted average contract price per bbl $ 59.47 $ 60.42 Natural gas swaps: Contract volumes (10,000 MMBTU) 46 — Weighted average price differential per MMBTU $ 0.47 $ — Natural gas futures: Contract volumes (10,000 MMBTU) 90 126 Weighted average contract price per MMBTU $ 2.56 $ 2.55 Crude oil options: Contract volumes (1,000 bbls) 16 — Weighted average premium received/paid $ 4.68 $ — 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 margin deposits necessary to fund unrealized losses also affect cash flows from operating activities. The following tables reflect the estimated fair value gain (loss) position of our derivatives at March 31, 2021 and December 31, 2020: Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, 2020 Asset Derivatives: Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 243 $ 732 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (243) (732) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Natural Gas Swap (undesignated hedge) Current Assets - Other 127 616 Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized assets Current Assets - Other $ 670 $ 1,022 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (670) (1,022) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (70,810) (52,372) Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued Liabilities — — Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (505) $ (2,114) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 505 2,114 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (892) $ (3,345) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 892 3,073 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ (272) (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 amounts associated with cash margin. 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 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, 2021, we had a net broker receivable of approximately $1.8 million (consisting of initial margin of $1.1 million increased by $0.7 million of variation margin). As of December 31, 2020, we had a net broker receivable of approximately $3.4 million (consisting of initial margin of $3.3 million increased by $0.1 million of variation margin). At March 31, 2021 and December 31, 2020, 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, net in our Unaudited Condensed Consolidated Statement of Operations. At March 31, 2021, the fair value of this embedded derivative was a liability of $70.8 million. See Note 10 for additional information regarding our Class A Convertible Preferred Units and the Rate Reset Election. Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended March 31, 2021 2020 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (5,897) $ 729 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs (3,921) (1,375) Total commodity derivatives $ (9,818) $ (646) Natural Gas Swap Liability Sodium minerals and sulfur services operating costs $ (67) $ (432) Preferred Distribution Rate Reset Election Other income (expense) $ (18,438) $ 32,545

Fair-Value Measurements

Fair-Value Measurements3 Months Ended
Mar. 31, 2021
Fair Value Disclosures [Abstract]
Fair-Value MeasurementsFair-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, 2021 and December 31, 2020. Fair Value at Fair Value at March 31, 2021 December 31, 2020 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 913 $ 127 $ — $ 1,754 $ 616 $ — Liabilities $ (1,397) $ — $ — $ (5,459) $ — $ — Preferred Distribution Rate Reset Election $ — $ — $ (70,810) $ — $ — $ (52,372) 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: Three Months Ended 2021 Balance as of December 31, 2020 $ (52,372) Unrealized loss for the period included in earnings (18,438) Balance as of March 31, 2021 $ (70,810) 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, 2021. 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, credit spread, default probabilities, equity volatility and timing estimates which involve management judgment. Our equity volatility rate used to value our embedded derivative feature was 50% at March 31, 2021. 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, as well as the passage of time as we draw nearer to our coupon rate reset date in 2022, we recorded an unrealized loss of $18.4 million for the 2021 Quarter. During the 2020 Quarter, we recorded an unrealized gain of $32.5 million due to the significant changes in the energy industry credit markets and our common unit price during the period. The unrealized loss in the 2021 Quarter and the unrealized gain in the 2020 Quarter are recorded within "Other income (expense)" on the Unaudited Condensed Consolidated Statements of Operations. See Note 15 for additional information on our derivative instruments. Other Fair Value Measurements We believe the debt outstanding under our 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, 2021 our senior unsecured notes had a carrying value and fair value of $2.7 billion compared to a carrying value of $2.8 billion and fair value of $2.7 billion at December 31, 2020. 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 Contingencies3 Months Ended
Mar. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and ContingenciesCommitments 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 Events3 Months Ended
Mar. 31, 2021
Subsequent Events [Abstract]
Subsequent EventsSubsequent EventsOn 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, comprising a term loan facility of $300 million and a revolving loan facility of $650 million, with the ability to increase the aggregate size of the revolving loan facility by an additional $200 million subject to lender consent and certain other customary conditions. The new credit agreement matures on March 15, 2024, subject to extension at our request for one

Recent Accounting Developments

Recent Accounting Developments (Policies)3 Months Ended
Mar. 31, 2021
Accounting Policies [Abstract]
Basis of Presentation and ConsolidationBasis 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, 2020 (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.
Recently Accounting DevelopmentsRecent Accounting DevelopmentsRecently Adopted    During the first quarter of 2020, the SEC amended the financial disclosure requirements for guarantors and issuers of guaranteed securities registered or being registered in Rule 3-10 of Regulation S-X to go in effect January 4, 2021. The amendment simplifies the disclosure requirements and permits the amended disclosures to be provided outside the footnotes in audited annual or unaudited interim consolidated financial statements in all filings. As permitted by the amendment, we have early adopted the amendment and included the required summarized financial information in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

Revenue Recognition (Tables)

Revenue Recognition (Tables)3 Months Ended
Mar. 31, 2021
Revenue Recognition [Abstract]
Schedule of Disaggregation of RevenueThe following tables reflect the disaggregation of our revenues by major category for the 2021 Quarter and the three months ended March 31, 2020 (the "2020 Quarter"), respectively: 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 Three Months Ended Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Marine Transportation Onshore Facilities & Transportation Consolidated Fee-based revenues $ 78,429 $ — $ 62,346 $ 40,990 $ 181,765 Product Sales — 215,366 — 114,768 330,134 Refinery Services — 28,024 — — 28,024 $ 78,429 $ 243,390 $ 62,346 $ 155,758 $ 539,923
Schedule of Contract Asset and Liabilities Balances ActivityThe table below depicts our contract asset and liability balances at December 31, 2020 and March 31, 2021: Contract Assets Contract Liabilities Current Non-Current Current Non-Current Balance at December 31, 2020 $ 36,500 $ 12,065 $ 2,988 $ 19,834 Balance at March 31, 2021 35,930 3,174 2,849 19,187
Schedule of Revenue Expected to be Recognized in Future PeriodsThe following chart depicts how we expect to recognize revenues for future periods related to these contracts: Offshore Pipeline Transportation Onshore Facilities and Transportation Remainder of 2021 $ 48,198 $ 14,369 2022 75,623 4,703 2023 63,982 — 2024 56,326 — 2025 60,311 — Thereafter 97,761 — Total $ 402,201 $ 19,072

Lease Accounting (Tables)

Lease Accounting (Tables)3 Months Ended
Mar. 31, 2021
Leases [Abstract]
Schedule of Lease Revenues for Operating LeasesOur lease revenues for these arrangements (inclusive of fixed and variable consideration) are reflected in the table below: Three Months Ended 2021 2020 M/T American Phoenix $ 3,420 $ 6,643 Free State Pipeline (1) — 1,923

Inventories (Tables)

Inventories (Tables)3 Months Ended
Mar. 31, 2021
Inventory Disclosure [Abstract]
Schedule of Major Components of InventoriesThe major components of inventories were as follows: March 31, December 31, 2020 Petroleum products $ 2,584 $ 5,840 Crude oil 14,633 37,661 Caustic soda 5,108 5,167 NaHS 7,736 9,101 Raw materials - Alkali operations 6,492 7,120 Work-in-process - Alkali operations 10,700 9,355 Finished goods, net - Alkali operations 11,988 13,002 Materials and supplies, net - Alkali operations 13,186 12,631 Total $ 72,427 $ 99,877

Fixed Assets, Mineral Leaseho_2

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Tables)3 Months Ended
Mar. 31, 2021
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule of Fixed AssetsFixed assets, net consisted of the following: March 31, 2021 December 31, 2020 Crude oil pipelines and natural gas pipelines and related assets $ 2,810,931 $ 2,811,030 Alkali facilities, machinery, and equipment 635,446 622,598 Onshore facilities, machinery, and equipment 268,571 267,810 Transportation equipment 19,520 19,470 Marine vessels 1,002,601 998,553 Land, buildings and improvements 220,454 219,382 Office equipment, furniture and fixtures 22,096 22,001 Construction in progress 183,628 170,740 Other 43,261 41,891 Fixed assets, at cost 5,206,508 5,173,475 Less: Accumulated depreciation (1,381,384) (1,322,141) Net fixed assets $ 3,825,124 $ 3,851,334
Schedule of Mineral LeaseholdsOur Mineral Leaseholds, relating to our Alkali Business, consist of the following: March 31, December 31, 2020 Mineral leaseholds $ 566,019 $ 566,019 Less: Accumulated depletion (14,356) (13,444) Mineral leaseholds, net of accumulated depletion $ 551,663 $ 552,575
Schedule of Depreciation and Depletion ExpenseOur depreciation and depletion expense for the periods presented was as follows: Three Months Ended March 31, 2021 2020 Depreciation expense $ 62,702 $ 69,242 Depletion expense 912 963
Schedule of Change in Asset Retirement ObligationThe following table presents information regarding our AROs since December 31, 2020: ARO liability balance, December 31, 2020 $ 176,852 Accretion expense 2,584 Changes in estimate 797 Settlements (2,017) ARO liability balance, March 31, 2021 $ 178,216
Schedule of Forecast of Accretion Expense of Asset Retirement ObligationsWith respect to our AROs, the following table presents our estimate of accretion expense for the periods indicated: Remainder of 2021 $ 7,532 2022 $ 9,384 2023 $ 9,128 2024 $ 9,783 2025 $ 10,487

Equity Investees (Tables)

Equity Investees (Tables)3 Months Ended
Mar. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Consolidated Financial Statements Related to Equity InvesteesThe following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees: Three Months Ended March 31, 2021 2020 Genesis’ share of operating earnings $ 24,533 $ 18,032 Amortization of excess purchase price (3,873) (3,873) Net equity in earnings $ 20,660 $ 14,159 Distributions received $ 29,516 $ 20,565
Schedule of Balance Sheet Information for Equity InvesteesThe following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company, L.L.C. ("Poseidon") (which is our most significant equity investment): March 31, December 31, 2020 BALANCE SHEET DATA: Assets Current assets $ 17,531 $ 30,465 Fixed assets, net 168,723 171,732 Other assets 5,036 4,673 Total assets $ 191,290 $ 206,870 Liabilities and equity Current liabilities $ 11,720 $ 9,958 Other liabilities 229,008 237,595 Equity (49,438) (40,683) Total liabilities and equity $ 191,290 $ 206,870
Schedule Of Operations For Equity Investees Three Months Ended March 31, 2021 2020 INCOME STATEMENT DATA: Revenues $ 42,413 $ 32,892 Operating income $ 32,161 $ 23,606 Net income $ 31,145 $ 21,583

Intangible Assets (Tables)

Intangible Assets (Tables)3 Months Ended
Mar. 31, 2021
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of Components of Intangible AssetsThe following table summarizes the components of our intangible assets at the dates indicated: March 31, 2021 December 31, 2020 Gross Accumulated Carrying Gross Accumulated Carrying Marine contract intangibles $ 800 $ 580 $ 220 $ 800 $ 571 $ 229 Offshore pipeline contract intangibles 158,101 47,153 110,948 158,101 45,073 113,028 Other 30,949 14,269 16,680 29,244 13,759 15,485 Total $ 189,850 $ 62,002 $ 127,848 $ 188,145 $ 59,403 $ 128,742
Schedule of Amortization ExpenseOur amortization of intangible assets for the periods presented was as follows: Three Months Ended March 31, 2021 2020 Amortization of intangible assets $ 2,600 $ 4,116
Schedule of Expected Amortization ExpenseWe estimate that our amortization expense for the next five years will be as follows: Remainder of 2021 $ 8,323 2022 $ 10,973 2023 $ 10,705 2024 $ 10,390 2025 $ 10,222

Debt (Tables)

Debt (Tables)3 Months Ended
Mar. 31, 2021
Debt Disclosure [Abstract]
Schedule of Obligations Under Debt ArrangementsOur obligations under debt arrangements consisted of the following: March 31, 2021 December 31, 2020 Principal Unamortized Debt Issuance Costs (1) Net Value Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Senior secured credit facility $ 699,000 $ — $ 699,000 $ 643,700 $ — $ 643,700 6.000% senior unsecured notes due 2023 — — — 80,859 504 80,355 5.625% senior unsecured notes due 2024 341,135 2,749 338,386 341,135 2,963 338,172 6.500% senior unsecured notes due 2025 534,834 5,343 529,491 534,834 5,639 529,195 6.250% senior unsecured notes due 2026 359,799 3,994 355,805 359,799 4,189 355,610 8.000% senior unsecured notes due 2027 750,000 12,524 737,476 750,000 13,022 736,978 7.750% senior unsecured notes due 2028 720,975 10,871 710,104 720,975 11,269 709,706 Total long-term debt $ 3,405,743 $ 35,481 $ 3,370,262 $ 3,431,302 $ 37,586 $ 3,393,716 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in Other Long Term Assets on the Unaudited Condensed Consolidated Balance Sheets) were $4.8 million and $5.8 million as of March 31, 2021 and December 31, 2020, respectively.

Partners' Capital, Mezzanine _2

Partners' Capital, Mezzanine Capital and Distributions (Tables)3 Months Ended
Mar. 31, 2021
Equity [Abstract]
Schedule of Paid DistributionsWe paid or will pay the following distributions to our common unitholders in 2020 and 2021: Distribution For Date Paid Per Unit Total 2020 1 st Quarter May 15, 2020 $ 0.15 $ 18,387 2 nd Quarter August 14, 2020 $ 0.15 $ 18,387 3 rd Quarter November 13, 2020 $ 0.15 $ 18,387 4 th Quarter February 12, 2021 $ 0.15 $ 18,387 2021 1 st Quarter May 14, 2021 (1) $ 0.15 $ 18,387 (1) This distribution was declared on April 7, 2021 and will be paid to unitholders of record as of April 30, 2021. Distribution For Date Paid Per Unit Total 2020 1 st Quarter May 15, 2020 $ 0.7374 $ 18,684 2 nd Quarter August 14, 2020 $ 0.7374 $ 18,684 3 rd Quarter November 13, 2020 $ 0.7374 $ 18,684 4 th Quarter February 12, 2021 $ 0.7374 $ 18,684 2021 1 st Quarter May 14, 2021 (1) $ 0.7374 $ 18,684 (1) This distribution was declared on April 7, 2021 and will be paid to unitholders of record as of April 30, 2021.
Schedule of Changes in Redeemable Noncontrolling InterestThe following table shows the change in our redeemable noncontrolling interest balance from December 31, 2020 to March 31, 2021: Balance as of December 31, 2020 $ 141,194 Issuance of preferred units, net of issuance costs (1) 19,561 PIK distribution 4,093 Redemption accretion 698 Tax distributions (1) (1,891) Balance as of March 31, 2021 $ 163,655

Net Income (Loss) Per Common _2

Net Income (Loss) Per Common Unit (Tables)3 Months Ended
Mar. 31, 2021
Net Income per Common Unit [Abstract]
Schedule of Computation of Earnings Per Share, Basic and DilutedThe following table reconciles net income (loss) and weighted average units used in computing basic and diluted net income (loss) per common unit (in thousands, except per unit amounts): Three Months Ended 2021 2020 Net Income (Loss) Attributable to Genesis Energy L.P. $ (34,224) $ 24,909 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (18,684) (18,684) Net Income (Loss) Available to Common Unitholders $ (52,908) $ 6,225 Weighted Average Outstanding Units 122,579 122,579 Basic and Diluted Net Income (Loss) per Common Unit $ (0.43) $ 0.05

Business Segment Information (T

Business Segment Information (Tables)3 Months Ended
Mar. 31, 2021
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by SegmentSegment 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, 2021 Segment Margin (a) $ 84,269 $ 43,720 $ 20,999 $ 7,109 $ 156,097 Capital expenditures (b) $ 11,528 $ 10,038 $ 1,099 $ 11,714 $ 34,379 Revenues: External customers $ 64,384 $ 229,306 $ 188,150 $ 39,379 $ 521,219 Intersegment (c) — (2,019) 1,067 952 $ — Total revenues of reportable segments $ 64,384 $ 227,287 $ 189,217 $ 40,331 $ 521,219 Three Months Ended March 31, 2020 Segment Margin (a) $ 85,246 $ 36,941 $ 28,099 $ 19,002 $ 169,288 Capital expenditures (b) $ 1,027 $ 14,975 $ 1,157 $ 14,232 $ 31,391 Revenues: External customers $ 78,429 $ 245,535 $ 156,799 $ 59,160 $ 539,923 Intersegment (c) — (2,145) (1,041) 3,186 $ — Total revenues of reportable segments $ 78,429 $ 243,390 $ 155,758 $ 62,346 $ 539,923 (a) A reconciliation of total Segment Margin to net income (loss) attributable to Genesis Energy, L.P. for the periods is presented below. (b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as contributions to equity investees, if any. (c) 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, 2020 Offshore pipeline transportation $ 2,169,156 $ 2,187,083 Sodium minerals and sulfur services 1,958,893 1,962,146 Onshore facilities and transportation 1,065,316 1,035,662 Marine transportation 715,404 711,058 Other assets 40,844 37,670 Total consolidated assets $ 5,949,613 $ 5,933,619
Schedule of Reconciliation of Operating Profit (Loss) from Segments to ConsolidatedReconciliation of total Segment Margin to net income (loss) attributable to Genesis Energy, L.P.: Three Months Ended March 31, 2021 2020 Total Segment Margin $ 156,097 $ 169,288 Corporate general and administrative expenses (11,152) (6,492) Depreciation, depletion, amortization and accretion (68,997) (75,978) Interest expense (57,829) (54,965) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (8,856) (6,406) Other non-cash items (2) (18,444) 33,261 Distribution from unrestricted subsidiaries not included in income (3) (17,500) (2,238) Loss on extinguishment of debt (4) (1,627) (23,480) Differences in timing of cash receipts for certain contractual arrangements (5) (299) (4,490) Provision for leased items no longer in use (604) 130 Redeemable noncontrolling interest redemption value adjustments (6) (4,791) (4,086) Income tax (expense) benefit (222) 365 Net income (loss) attributable to Genesis Energy, L.P. $ (34,224) $ 24,909 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) The 2021 Quarter and 2020 Quarter include a $18.4 million unrealized loss and $32.5 million unrealized gain, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. Refer to Note 16 for details. (3) The 2021 Quarter and 2020 Quarter include $17.5 million and $2.2 million, respectively, in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility. See N ote 4 for details. (4) The 2021 Quarter includes the transaction costs and write-off of the unamortized issuance costs associated with the redemption of our remaining 2023 Notes. The 2020 Quarter includes the transaction costs associated with the tender and redemption of our 2022 Notes, along with the write-off of the unamortized issuance costs and discount associated with these notes. Refer to Note 9 for details. (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, 2021
Related Party Transactions [Abstract]
Schedule Of Transactions with Related PartiesThe transactions with related parties were as follows: Three Months Ended March 31, 2021 2020 Revenues: Revenues from services and fees to Poseidon (1) $ 3,786 $ 3,147 Revenues from product sales to ANSAC 67,955 73,079 Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon (1) 240 254 Charges for services from ANSAC 178 832 (1) We own a 64% interest in Poseidon Receivables from and payables to ANSAC as of March 31, 2021 and December 31, 2020 are as follows: March 31, December 31, 2021 2020 Receivables: ANSAC $ 52,972 $ 43,400 Payables: ANSAC $ 349 $ 470

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)3 Months Ended
Mar. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Net Changes In Components of Operating Assets and LiabilitiesThe following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended March 31, 2021 2020 (Increase) decrease in: Accounts receivable $ (99,504) $ 101,405 Inventories 27,450 (5,024) Deferred charges 7,731 2,783 Other current assets (2,294) (3,746) Increase (decrease) in: Accounts payable 38,994 (62,365) Accrued liabilities 22,561 (25,519) Net changes in components of operating assets and liabilities $ (5,062) $ 7,534

Derivatives (Tables)

Derivatives (Tables)3 Months Ended
Mar. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase CommitmentsAt March 31, 2021, we entered into the following outstanding derivative commodity contracts to economically hedge inventory or fixed price purchase commitments. Sell (Short) Buy (Long) Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 92 — Weighted average contract price per bbl $ 56.75 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 411 318 Weighted average contract price per bbl $ 59.47 $ 60.42 Natural gas swaps: Contract volumes (10,000 MMBTU) 46 — Weighted average price differential per MMBTU $ 0.47 $ — Natural gas futures: Contract volumes (10,000 MMBTU) 90 126 Weighted average contract price per MMBTU $ 2.56 $ 2.55 Crude oil options: Contract volumes (1,000 bbls) 16 — Weighted average premium received/paid $ 4.68 $ —
Schedule of Fair Value of Derivative Assets and LiabilitiesThe following tables reflect the estimated fair value gain (loss) position of our derivatives at March 31, 2021 and December 31, 2020: Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, 2020 Asset Derivatives: Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 243 $ 732 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (243) (732) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Natural Gas Swap (undesignated hedge) Current Assets - Other 127 616 Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized assets Current Assets - Other $ 670 $ 1,022 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (670) (1,022) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (70,810) (52,372) Natural Gas Swap (undesignated hedge) Current Liabilities -Accrued Liabilities — — Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (505) $ (2,114) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 505 2,114 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (892) $ (3,345) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 892 3,073 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ (272) (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 ResultsEffect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended March 31, 2021 2020 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (5,897) $ 729 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs (3,921) (1,375) Total commodity derivatives $ (9,818) $ (646) Natural Gas Swap Liability Sodium minerals and sulfur services operating costs $ (67) $ (432) Preferred Distribution Rate Reset Election Other income (expense) $ (18,438) $ 32,545

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)3 Months Ended
Mar. 31, 2021
Fair Value Disclosures [Abstract]
Schedule of Placement of Assets and Liabilities Within the Fair Value Hierarchy LevelsThe 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, 2021 and December 31, 2020. Fair Value at Fair Value at March 31, 2021 December 31, 2020 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 913 $ 127 $ — $ 1,754 $ 616 $ — Liabilities $ (1,397) $ — $ — $ (5,459) $ — $ — Preferred Distribution Rate Reset Election $ — $ — $ (70,810) $ — $ — $ (52,372)
Schedule of Reconciliation of Changes in Fair Value of Derivatives Classified as Level 3The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3: Three Months Ended 2021 Balance as of December 31, 2020 $ (52,372) Unrealized loss for the period included in earnings (18,438) Balance as of March 31, 2021 $ (70,810)

Organization and Basis of Pre_2

Organization and Basis of Presentation and Consolidation (Details)3 Months Ended
Mar. 31, 2021segment
Other Ownership Interests [Line Items]
Number of reportable segments4
Genesis Energy, LLC
Other Ownership Interests [Line Items]
Limited Partners' ownership percentage100.00%

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregated Revenue) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Disaggregation of Revenue [Line Items]
Total revenues $ 521,219 $ 539,923
Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues129,109 181,765
Product Sales
Disaggregation of Revenue [Line Items]
Total revenues369,601 330,134
Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues22,509 28,024
Offshore Pipeline Transportation
Disaggregation of Revenue [Line Items]
Total revenues64,384 78,429
Offshore Pipeline Transportation | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues64,384 78,429
Offshore Pipeline Transportation | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues0 0
Offshore Pipeline Transportation | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues0 0
Sodium Minerals & Sulfur Services
Disaggregation of Revenue [Line Items]
Total revenues227,287 243,390
Sodium Minerals & Sulfur Services | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues0 0
Sodium Minerals & Sulfur Services | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues204,778 215,366
Sodium Minerals & Sulfur Services | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues22,509 28,024
Marine Transportation
Disaggregation of Revenue [Line Items]
Total revenues40,331 62,346
Marine Transportation | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues40,331 62,346
Marine Transportation | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues0 0
Marine Transportation | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues0 0
Onshore Facilities and Transportation
Disaggregation of Revenue [Line Items]
Total revenues189,217 155,758
Onshore Facilities and Transportation | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues24,394 40,990
Onshore Facilities and Transportation | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues164,823 114,768
Onshore Facilities and Transportation | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues $ 0 $ 0

Revenue Recognition (Contract A

Revenue Recognition (Contract Assets and Liabilities) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Revenue Recognition [Abstract]
Contract Assets, Current $ 35,930 $ 36,500
Contract Assets, Non-Current3,174 12,065
Contract Liability, Current2,849 2,988
Contract Liabilities, Non-Current $ 19,187 $ 19,834

Revenue Recognition (Revenue Ex

Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in ThousandsMar. 31, 2021USD ($)
Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 402,201
Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods19,072
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 48,198
Revenue expected timing of satisfaction period9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 14,369
Revenue expected timing of satisfaction period9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 75,623
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 4,703
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 63,982
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 0
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 56,326
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 0
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 60,311
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 0
Revenue expected timing of satisfaction period1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 97,761
Revenue expected timing of satisfaction period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | Onshore Facilities and Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue expected to be recognized in future periods $ 0
Revenue expected timing of satisfaction period

Lease Accounting (Operating Lea

Lease Accounting (Operating Lease Income- Lessors) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Marine Transportation
Lessor, Lease, Description [Line Items]
Operating lease income $ 3,420 $ 6,643
Onshore Facilities and Transportation
Lessor, Lease, Description [Line Items]
Operating lease income $ 0 $ 1,923

Lease Accounting (Narrative) (D

Lease Accounting (Narrative) (Details) - Genesis NEJD Pipeline, LLC3 Months Ended
Mar. 31, 2021USD ($)Mar. 31, 2020USD ($)Oct. 30, 2020installment
Lessor, Lease, Description [Line Items]
Direct financing lease, number of installments | installment4
Collections received from direct finance lease receivable $ 17,500,000 $ 2,200,000
Direct finance lease receivable $ 52,500,000

Inventories (Major Components o

Inventories (Major Components of Inventories) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Inventory Disclosure [Abstract]
Petroleum products $ 2,584 $ 5,840
Crude oil14,633 37,661
Caustic soda5,108 5,167
NaHS7,736 9,101
Raw materials - Alkali operations6,492 7,120
Work-in-process - Alkali operations10,700 9,355
Finished goods, net - Alkali operations11,988 13,002
Materials and supplies, net - Alkali operations13,186 12,631
Total $ 72,427 $ 99,877

Inventories (Narrative) (Detail

Inventories (Narrative) (Details) - USD ($)3 Months Ended12 Months Ended
Mar. 31, 2021Dec. 31, 2020
Inventory Disclosure [Abstract]
Inventory write-down $ 400,000 $ 5,000,000

Fixed Assets, Mineral Leaseho_3

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Fixed Assets, Net) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Fixed assets, at cost $ 5,206,508 $ 5,173,475
Less: Accumulated depreciation(1,381,384)(1,322,141)
Net fixed assets3,825,124 3,851,334
Crude oil pipelines and natural gas pipelines and related assets
Property, Plant and Equipment [Line Items]
Fixed assets, at cost2,810,931 2,811,030
Onshore facilities, machinery, and equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost268,571 267,810
Onshore facilities, machinery, and equipment | Alkali Business
Property, Plant and Equipment [Line Items]
Fixed assets, at cost635,446 622,598
Transportation equipment
Property, Plant and Equipment [Line Items]
Fixed assets, at cost19,520 19,470
Marine vessels
Property, Plant and Equipment [Line Items]
Fixed assets, at cost1,002,601 998,553
Land, buildings and improvements
Property, Plant and Equipment [Line Items]
Fixed assets, at cost220,454 219,382
Office equipment, furniture and fixtures
Property, Plant and Equipment [Line Items]
Fixed assets, at cost22,096 22,001
Construction in progress
Property, Plant and Equipment [Line Items]
Fixed assets, at cost183,628 170,740
Other
Property, Plant and Equipment [Line Items]
Fixed assets, at cost $ 43,261 $ 41,891

Fixed Assets, Mineral Leaseho_4

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Mineral Leaseholds) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Fixed Assets And Asset Retirement Obligations [Abstract]
Mineral leaseholds $ 566,019 $ 566,019
Less: Accumulated depletion(14,356)(13,444)
Mineral leaseholds, net of accumulated depletion $ 551,663 $ 552,575

Fixed Assets, Mineral Leaseho_5

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense $ 62,702 $ 69,242
Depletion expense $ 912 $ 963

Fixed Assets, Mineral Leaseho_6

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Asset Retirement Obligation Rollforward) (Details) $ in Thousands3 Months Ended
Mar. 31, 2021USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2020 $ 176,852
Accretion expense2,584
Changes in estimate797
Settlements(2,017)
ARO liability balance, March 31, 2021 $ 178,216

Fixed Assets, Mineral Leaseho_7

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance $ 178,216 $ 176,852
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance $ 13,600 $ 14,700

Fixed Assets, Mineral Leaseho_8

Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations (Forecast of Accretion Expense) (Details) $ in ThousandsMar. 31, 2021USD ($)
Fixed Assets And Asset Retirement Obligations [Abstract]
Remainder of 2021 $ 7,532
20229,384
20239,128
20249,783
2025 $ 10,487

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in MillionsMar. 31, 2021Dec. 31, 2020
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount $ 331.5 $ 335.4

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Equity Method Investments and Joint Ventures [Abstract]
Genesis’ share of operating earnings $ 24,533 $ 18,032
Amortization of excess purchase price(3,873)(3,873)
Net equity in earnings20,660 14,159
Distributions received $ 29,516 $ 20,565

Equity Investees (Schedule of B

Equity Investees (Schedule of Balance Sheet Information for Equity Investees) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Assets
Current assets $ 644,143 $ 580,169
Fixed assets, net3,825,124 3,851,334
Total assets5,949,613 5,933,619
LIABILITIES AND CAPITAL
Current liabilities454,094 383,411
Total liabilities and equity5,949,613 5,933,619
Equity Method Investment, Nonconsolidated Investee or Group of Investees | Poseidon
Assets
Current assets17,531 30,465
Fixed assets, net168,723 171,732
Other assets5,036 4,673
Total assets191,290 206,870
LIABILITIES AND CAPITAL
Current liabilities11,720 9,958
Other liabilities229,008 237,595
Equity(49,438)(40,683)
Total liabilities and equity $ 191,290 $ 206,870

Equity Investees (Schedule of O

Equity Investees (Schedule of Operations for Equity Investees) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
INCOME STATEMENT DATA:
Revenues $ 521,219 $ 539,923
Operating income28,021 59,162
Net income(34,224)24,909
Equity Method Investment, Nonconsolidated Investee or Group of Investees | Poseidon
INCOME STATEMENT DATA:
Revenues42,413 32,892
Operating income32,161 23,606
Net income $ 31,145 $ 21,583

Intangible Assets (Schedule of

Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount $ 189,850 $ 188,145
Accumulated Amortization62,002 59,403
Carrying Value127,848 128,742
Contract intangibles | Marine Transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount800 800
Accumulated Amortization580 571
Carrying Value220 229
Contract intangibles | Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount158,101 158,101
Accumulated Amortization47,153 45,073
Carrying Value110,948 113,028
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount30,949 29,244
Accumulated Amortization14,269 13,759
Carrying Value $ 16,680 $ 15,485

Intangible Assets (Schedule o_2

Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Amortization of intangible assets $ 2,600 $ 4,116
Remainder of 20218,323
202210,973
202310,705
202410,390
2025 $ 10,222

Debt (Schedule of Obligations U

Debt (Schedule of Obligations Under Debt Arrangements) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Debt Instrument [Line Items]
Principal $ 3,405,743 $ 3,431,302
Unamortized Debt Issuance Costs35,481 37,586
Net Value3,370,262 3,393,716
Senior secured credit facility
Debt Instrument [Line Items]
Principal699,000 643,700
Unamortized Debt Issuance Costs0 0
Net Value699,000 643,700
Unamortized debt issuance costs included in other long term debt assets $ 4,800 $ 5,800
6.000% senior unsecured notes due 2023
Debt Instrument [Line Items]
Senior unsecured notes, stated rate600.00%600.00%
Principal $ 0 $ 80,859
Unamortized Debt Issuance Costs0 504
Net Value $ 0 $ 80,355
5.625% senior unsecured notes due 2024
Debt Instrument [Line Items]
Senior unsecured notes, stated rate562.50%562.50%
Principal $ 341,135 $ 341,135
Unamortized Debt Issuance Costs2,749 2,963
Net Value $ 338,386 $ 338,172
6.500% senior unsecured notes due 2025
Debt Instrument [Line Items]
Senior unsecured notes, stated rate650.00%650.00%
Principal $ 534,834 $ 534,834
Unamortized Debt Issuance Costs5,343 5,639
Net Value $ 529,491 $ 529,195
6.250% senior unsecured notes due 2026
Debt Instrument [Line Items]
Senior unsecured notes, stated rate625.00%625.00%
Principal $ 359,799 $ 359,799
Unamortized Debt Issuance Costs3,994 4,189
Net Value $ 355,805 $ 355,610
8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Senior unsecured notes, stated rate800.00%800.00%
Principal $ 750,000 $ 750,000
Unamortized Debt Issuance Costs12,524 13,022
Net Value $ 737,476 $ 736,978
7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Senior unsecured notes, stated rate775.00%775.00%
Principal $ 720,975 $ 720,975
Unamortized Debt Issuance Costs10,871 11,269
Net Value $ 710,104 $ 709,706

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)Apr. 22, 2021Dec. 17, 2020Feb. 16, 2020Jan. 16, 2020Mar. 31, 2021Mar. 31, 2020Apr. 08, 2021Jan. 19, 2021Dec. 31, 2020
Debt Instrument [Line Items]
Loss on extinguishment of debt $ 1,627,000 $ 23,480,000
Repayments of Unsecured Debt80,859,000 750,000,000
Principal $ 3,405,743,000 $ 3,431,302,000
7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Senior unsecured notes, stated rate775.00%775.00%
Principal $ 720,975,000 $ 720,975,000
8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Senior unsecured notes, stated rate800.00%800.00%
Principal $ 750,000,000 $ 750,000,000
6.000% senior unsecured notes due 2023
Debt Instrument [Line Items]
Senior unsecured notes, stated rate600.00%600.00%
Principal $ 0 $ 80,859,000
Senior secured credit facility
Debt Instrument [Line Items]
Principal $ 699,000,000 $ 643,700,000
Credit Facility | Federal Funds Effective Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate0.50%
Credit Facility | Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate3.50%
Credit Facility | Applicable Margin
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate2.50%
Credit Facility | Minimum
Debt Instrument [Line Items]
Letter of credit, fee percentage1.75%
Credit Facility | Minimum | Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate1.75%
Credit Facility | Minimum | Alternate Base Rate
Debt Instrument [Line Items]
Letter of credit, fee percentage0.75%
Credit Facility | Maximum
Debt Instrument [Line Items]
Letter of credit, fee percentage3.50%
Credit Facility | Maximum | Federal Funds Effective Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate1.00%
Credit Facility | Maximum | LIBOR Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate1.00%
Credit Facility | Maximum | Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate3.50%
Credit Facility | Maximum | Alternate Base Rate
Debt Instrument [Line Items]
Letter of credit, fee percentage2.50%
Credit Facility | Accordion Feature
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity $ 300,000,000
Line of credit facility aggregate maximum borrowing capacity2,000,000,000
Credit Facility | Senior secured credit facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity $ 1,700,000,000
Letter of credit, fee percentage3.50%
Line of credit, unused capacity commitment fee percentage0.50%
Credit facility, amount outstanding $ 699,000,000
Letters of credit, outstanding amount1,300,000
Total amount available for borrowings under credit facility999,700,000
Credit Facility | Senior secured credit facility | Subsequent Event
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity $ 950,000,000
Credit Facility | Senior secured credit facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount outstanding $ 13,000,000
Credit Facility | Senior secured credit facility | Minimum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage0.25%
Credit Facility | Senior secured credit facility | Maximum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage0.50%
Letters of credit, outstanding amount $ 200,000,000
Senior Notes | 7.750% senior unsecured notes due 2028
Debt Instrument [Line Items]
Debt issued $ 750,000,000
Senior unsecured notes, stated rate7.75%
Proceeds from issuance of debt $ 736,700,000
Senior Notes | 8.000% senior unsecured notes due 2027
Debt Instrument [Line Items]
Debt issued $ 750,000,000
Senior unsecured notes, stated rate8.00%
Proceeds from issuance of debt $ 737,000,000
Senior Notes | 8.000% senior unsecured notes due 2027 | Subsequent Event
Debt Instrument [Line Items]
Debt issued $ 250,000,000
Debt premium percentage103.75%
Senior Notes | 6.75% Percent Notes Due 2022
Debt Instrument [Line Items]
Senior unsecured notes, stated rate6.75%
Proceeds used to repay unsecured debt principal $ 222,100,000 $ 554,800,000
Loss on extinguishment of debt $ 23,500,000
Senior Notes | 6.000% senior unsecured notes due 2023
Debt Instrument [Line Items]
Senior unsecured notes, stated rate6.00%
Loss on extinguishment of debt $ 1,600,000
Repayments of Unsecured Debt $ 316,500,000
Principal $ 80,900,000

Partners' Capital, Mezzanine _3

Partners' Capital, Mezzanine Capital and Distributions (Common Cash Distributions Paid) (Details) - Common Unitholders - USD ($) $ / shares in Units, $ in ThousandsMay 14, 2021Feb. 12, 2021Nov. 13, 2020Aug. 14, 2020May 15, 2020
Partners Capital And Distributions [Line Items]
Date PaidFeb. 12,
2021
Nov. 13,
2020
Aug. 14,
2020
May 15,
2020
Per Unit Amount (in dollars per unit) $ 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 PaidMay 14,
2021
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) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020Dec. 31, 2020
Temporary Equity [Line Items]
Common units outstanding (in units)122,579,218 122,579,218
Preferred units, accumulated distributions $ 18,684 $ 18,684
Common Class A | Partners’ Capital
Temporary Equity [Line Items]
Common units outstanding (in units)122,539,221
Common Class B | Partners’ Capital
Temporary Equity [Line Items]
Common units outstanding (in units)39,997
Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Number of preferred units outstanding (in units)25,336,778 25,336,778
Preferred units, accumulated distributions $ 18,700 $ 18,700

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 ThousandsMay 14, 2021Feb. 12, 2021Nov. 13, 2020Aug. 14, 2020May 15, 2020
Temporary Equity [Line Items]
Date PaidFeb. 12,
2021
Nov. 13,
2020
Aug. 14,
2020
May 15,
2020
Per Unit Amount (in dollars per unit) $ 0.7374 $ 0.7374 $ 0.7374
Total Amount $ 18,684 $ 18,684 $ 18,684 $ 18,684
Forecast | Subsequent Event
Temporary Equity [Line Items]
Date PaidMay 14,
2021
Per Unit Amount (in dollars per unit) $ 0.7374
Total Amount $ 18,684

Partners' Capital, Mezzanine _6

Partners' Capital, Mezzanine Capital and Distributions (Redeemable Noncontrolling Interest - Narrative) (Details) - USD ($)Apr. 14, 2020Sep. 23, 2019Mar. 31, 2021Mar. 31, 2020Dec. 31, 2020
Redeemable Noncontrolling Interest [Line Items]
Redeemable noncontrolling interest redemption value adjustments $ 4,791,000 $ 4,086,000
Redeemable noncontrolling interest redemption value adjustments allocated to PIK distributions4,093,000
Redemption accretion fair value adjustment $ 698,000
Redeemable Noncontrolling Interest Preferred Units
Redeemable Noncontrolling Interest [Line Items]
Number of preferred units outstanding (in units)161,209 141,249
Subsidiary | Alkali Holdings
Redeemable Noncontrolling Interest [Line Items]
Issuance of redeemable noncontrolling interest $ 55,000,000
Facility expansion costs percentage100.00%
Expansion project extension period1 year
Equity preferred units issued (in shares)1,750 18,100
Commitment period4 years
Period for occurrence of triggering events6 years 6 months
Redeemable noncontrolling interest redemption value adjustments $ 4,800,000 4,100,000
Redeemable noncontrolling interest redemption value adjustments allocated to PIK distributions4,100,000 3,300,000
Redemption accretion fair value adjustment700,000 $ 800,000
Redemption value of redeemable preferred noncontrolling interest $ 212,900,000
Subsidiary | Alkali Holdings | Redeemable Noncontrolling Interest Preferred Units
Redeemable Noncontrolling Interest [Line Items]
Number of preferred units outstanding (in units)55,000 161,209
Subsidiary | Alkali Holdings | Maximum
Redeemable Noncontrolling Interest [Line Items]
Number of preferred units outstanding (in units)351,750
Redeemable noncontrolling interest preferred commitment $ 351,750,000 $ 350,000,000

Partners' Capital, Mezzanine _7

Partners' Capital, Mezzanine Capital and Distributions (Changes in Redeemable Noncontrolling Interests) (Details) - USD ($) $ in ThousandsApr. 14, 2020Mar. 31, 2021Mar. 31, 2020
Redeemable Noncontrolling Interest, Equity [Roll Forward]
Balance as of December 31, 2020 $ 141,194
Issuance of preferred units, net of issuance costs19,561
PIK distribution4,093
Redemption accretion698
Tax distributions (1)(1,891)
Balance as of March 31, 2021163,655
Subsidiary | Alkali Holdings
Redeemable Noncontrolling Interest, Equity [Roll Forward]
PIK distribution4,100 $ 3,300
Redemption accretion $ 700 $ 800
Redeemable Noncontrolling Interest [Line Items]
Equity preferred units issued to pay tax distributions (in shares)1,860
Equity preferred units issued (in shares)1,750 18,100

Net Income (Loss) Per Common _3

Net Income (Loss) Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Earnings Per Share Reconciliation [Abstract]
Net Income (loss) Attributable to Genesis Energy L.P. $ (34,224) $ 24,909
Less: Accumulated distributions attributable to Class A Convertible Preferred Units(18,684)(18,684)
NET INCOME (LOSS) AVAILABLE TO COMMON UNITHOLDERS $ (52,908) $ 6,225
Weighted Average Outstanding Units (in shares)122,579,000 122,579,000
Basic and Diluted Net Loss per Common Unit (in dollars per unit) $ (0.43) $ 0.05
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 shares)25,336,778

Business Segment Information (N

Business Segment Information (Narrative) (Details)3 Months Ended
Mar. 31, 2021segment
Segment Reporting [Abstract]
Number of reportable segments4

Business Segment Information (S

Business Segment Information (Schedule of Segment Information) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Segment Reporting Information [Line Items]
Segment margin $ 156,097 $ 169,288
Total revenues521,219 539,923
Offshore Pipeline Transportation
Segment Reporting Information [Line Items]
Total revenues64,384 78,429
Sodium Minerals & Sulfur Services
Segment Reporting Information [Line Items]
Total revenues227,287 243,390
Onshore Facilities and Transportation
Segment Reporting Information [Line Items]
Total revenues189,217 155,758
Marine Transportation
Segment Reporting Information [Line Items]
Total revenues40,331 62,346
Operating Segments
Segment Reporting Information [Line Items]
Segment margin156,097 169,288
Capital expenditures34,379 31,391
Total revenues521,219 539,923
Operating Segments | Offshore Pipeline Transportation
Segment Reporting Information [Line Items]
Segment margin84,269 85,246
Capital expenditures11,528 1,027
Total revenues64,384 78,429
Operating Segments | Sodium Minerals & Sulfur Services
Segment Reporting Information [Line Items]
Segment margin43,720 36,941
Capital expenditures10,038 14,975
Total revenues229,306 245,535
Operating Segments | Onshore Facilities and Transportation
Segment Reporting Information [Line Items]
Segment margin20,999 28,099
Capital expenditures1,099 1,157
Total revenues188,150 156,799
Operating Segments | Marine Transportation
Segment Reporting Information [Line Items]
Segment margin7,109 19,002
Capital expenditures11,714 14,232
Total revenues39,379 59,160
Intersegment
Segment Reporting Information [Line Items]
Total revenues0 0
Intersegment | Offshore Pipeline Transportation
Segment Reporting Information [Line Items]
Total revenues0 0
Intersegment | Sodium Minerals & Sulfur Services
Segment Reporting Information [Line Items]
Total revenues(2,019)(2,145)
Intersegment | Onshore Facilities and Transportation
Segment Reporting Information [Line Items]
Total revenues1,067 (1,041)
Intersegment | Marine Transportation
Segment Reporting Information [Line Items]
Total revenues $ 952 $ 3,186

Business Segment Information _2

Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Segment Reporting Information [Line Items]
Total consolidated assets $ 5,949,613 $ 5,933,619
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total consolidated assets2,169,156 2,187,083
Operating Segments | Sodium Minerals & Sulfur Services
Segment Reporting Information [Line Items]
Total consolidated assets1,958,893 1,962,146
Operating Segments | Onshore Facilities and Transportation
Segment Reporting Information [Line Items]
Total consolidated assets1,065,316 1,035,662
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Total consolidated assets715,404 711,058
Other assets
Segment Reporting Information [Line Items]
Total consolidated assets $ 40,844 $ 37,670

Business Segment Information (R

Business Segment Information (Reconciliation of Segment Margin to (Loss) Income from Continuing Operations) (Details) - USD ($)3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Segment Reporting [Abstract]
Total Segment Margin $ 156,097,000 $ 169,288,000
Corporate general and administrative expenses(11,152,000)(6,492,000)
Depreciation, depletion, amortization and accretion(68,997,000)(75,978,000)
Interest expense(57,829,000)(54,965,000)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)(8,856,000)(6,406,000)
Other non-cash items (2)(18,444,000)33,261,000
Distribution from unrestricted subsidiaries not included in income (3)(17,500,000)(2,238,000)
Loss on extinguishment of debt (4)(1,627,000)(23,480,000)
Differences in timing of cash receipts for certain contractual arrangements(299,000)(4,490,000)
Provision for leased items no longer in use(604,000)130,000
Redeemable noncontrolling interest redemption value adjustments(4,791,000)(4,086,000)
Income tax (expense) benefit(222,000)365,000
NET INCOME (LOSS) ATTRIBUTABLE TO GENESIS ENERGY, L.P.(34,224,000)24,909,000
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (loss) gain from valuation of embedded derivatives(17,599,000)31,118,000
Genesis NEJD Pipeline, LLC
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Collections received from direct finance lease receivable17,500,000 2,200,000
Embedded Derivative Financial Instruments
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Unrealized (loss) gain from valuation of embedded derivatives $ (18,400,000) $ 32,500,000

Transactions with Related Par_3

Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - Affiliated Entity - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
CEO
Related Party Transaction [Line Items]
Costs and expenses $ 165 $ 165
Poseidon
Related Party Transaction [Line Items]
Revenues3,786 3,147
Costs and expenses $ 240 254
Equity method investment, ownership percentage64.00%
ANSAC
Related Party Transaction [Line Items]
Revenues $ 67,955 73,079
Costs and expenses $ 178 $ 832

Transactions with Related Par_4

Transactions with Related Parties (Narrative) (Details) - Affiliated Entity - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020Dec. 31, 2020
Poseidon
Related Party Transaction [Line Items]
Related party transaction, revenues $ 3,786 $ 3,147
Due from related parties1,500 $ 2,600
Related party transaction, costs and expenses240 254
Poseidon | Asset Management Arrangement
Related Party Transaction [Line Items]
Related party transaction, revenues2,400 2,300
ANSAC
Related Party Transaction [Line Items]
Related party transaction, revenues67,955 73,079
Due from related parties52,972 $ 43,400
Related party transaction, costs and expenses $ 178 $ 832

Transactions with Related Par_5

Transactions with Related Parties (ANSAC) (Details) - ANSAC - Affiliated Entity - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Related Party Transaction [Line Items]
Receivables $ 52,972 $ 43,400
Payables $ 349 $ 470

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
(Increase) decrease in:
Accounts receivable $ (99,504) $ 101,405
Inventories27,450 (5,024)
Deferred charges7,731 2,783
Other current assets(2,294)(3,746)
Increase (decrease) in:
Accounts payable38,994 (62,365)
Accrued liabilities22,561 (25,519)
Net changes in components of operating assets and liabilities $ (5,062) $ 7,534

Supplemental Cash Flow Inform_4

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees $ 35.4 $ 33.7
Interest paid, capitalized0.7 0.5
Incurred liabilities for fixed and intangible asset additions $ 27.1 $ 17.2

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 Thousands3 Months Ended
Mar. 31, 2021MMBTU$ / MMBTU$ / bbl$ / unitsbbl
Designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl92
Weighted average contract price56.75
Designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl0
Weighted average contract price0
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl411
Weighted average contract price59.47
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU90
Weighted average contract price | $ / MMBTU2.56
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Swap | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU46
Weighted average contract price0.47
Not qualifying or not designated as hedges under accounting rules | Sell (Short) Contracts | Options | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl16
Weighted average premium received/paid4.68
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl318
Weighted average contract price60.42
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU126
Weighted average contract price | $ / MMBTU2.55
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Swap | Natural Gas
Derivative [Line Items]
Contract volume (MMBTU) | MMBTU0
Weighted average contract price | $ / units0
Not qualifying or not designated as hedges under accounting rules | Buy (Long) Contracts | Options | Crude Oil
Derivative [Line Items]
Contract volumes (bbls/gal) | bbl0
Weighted average premium received/paid0

Derivatives (Schedule of Fair V

Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in ThousandsMar. 31, 2021Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability $ (70,800)
Preferred Distribution Rate Reset Election | Other long-term liabilities
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability(70,810) $ (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 Asset243 732
Derivative Asset, Fair Value, Gross Liability(243)(732)
Asset Derivatives0 0
Derivative Liability, Fair Value, Gross Liability(505)(2,114)
Derivative Liability, Fair Value, Gross Asset505 2,114
Liability Derivatives0 0
Not qualifying or not designated as hedges under accounting rules | Swap | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset127 616
Not qualifying or not designated as hedges under accounting rules | Swap | Current Liabilities -Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability0 0
Designated as hedges under accounting rules | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset670 1,022
Derivative Asset, Fair Value, Gross Liability(670)(1,022)
Asset Derivatives0 0
Derivative Liability, Fair Value, Gross Liability(892)(3,345)
Derivative Liability, Fair Value, Gross Asset892 3,073
Liability Derivatives $ 0 $ (272)

Derivatives (Narrative) (Detail

Derivatives (Narrative) (Details) $ in MillionsSep. 01, 2022Mar. 31, 2021USD ($)Dec. 31, 2020USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Net broker receivable $ 1.8 $ 3.4
Initial margin1.1 3.3
Increase in variation margin0.7 $ 0.1
Derivatives, Fair Value [Line Items]
Embedded derivative liability $ 70.8
Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Period to notify holders30 days
Stock reset rate percentage10.75%
Percentage below issue price per share110.00%
LIBOR | Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price0.0750

Derivatives (Schedule of Effect

Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands3 Months Ended
Mar. 31, 2021Mar. 31, 2020
Commodity derivatives - futures and call options | Cost of Goods and Services Sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income $ (9,818) $ (646)
Natural Gas Swap Liability | 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(67)(432)
Preferred Distribution Rate Reset Election | Other income (expense)
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income(18,438)32,545
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(5,897)729
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 $ (3,921) $ (1,375)

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 ThousandsMar. 31, 2021Dec. 31, 2020
Level 1 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value $ 913 $ 1,754
Liabilities Fair Value(1,397)(5,459)
Level 1 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value0 0
Level 2 | Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value127 616
Liabilities Fair Value0 0
Level 2 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value0 0
Level 3 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value0 0
Liabilities Fair Value0 0
Level 3 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value $ (70,810) $ (52,372)

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 Thousands3 Months Ended
Mar. 31, 2021USD ($)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance as of December 31, 2020 $ (52,372)
Unrealized loss for the period included in earnings(18,438)
Balance as of March 31, 2021 $ (70,810)

Fair-Value Measurements (Narrat

Fair-Value Measurements (Narrative) (Details) $ in Thousands3 Months Ended
Mar. 31, 2021USD ($)Mar. 31, 2020USD ($)Dec. 31, 2020USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (loss) gain from valuation of embedded derivatives $ (17,599) $ 31,118
Carrying value of senior unsecured notes2,671,262 $ 2,750,016
Fair value of senior unsecured notes2,700,000 $ 2,700,000
Embedded Derivative Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized (loss) gain from valuation of embedded derivatives $ (18,400) $ 32,500
Equity Volatility
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Embedded derivative liability, measurement input0.50

Subsequent Events (Details)

Subsequent Events (Details)Apr. 22, 2021USD ($)Apr. 08, 2021USD ($)extensionMar. 31, 2021USD ($)Dec. 17, 2020USD ($)
Credit Facility | Senior secured credit facility
Subsequent Event [Line Items]
Credit facility, maximum borrowing capacity $ 1,700,000,000
Senior Notes | 8.000% senior unsecured notes due 2027
Subsequent Event [Line Items]
Debt issued $ 750,000,000
Subsequent Event | Credit Facility | Senior secured credit facility
Subsequent Event [Line Items]
Credit facility, maximum borrowing capacity $ 950,000,000
Credit facility, additional borrowing capacity $ 200,000,000
Credit facility, extension period1 year
Credit facility, number of extensions occasions | extension2
Subsequent Event | Credit Facility | Term Loan Facility
Subsequent Event [Line Items]
Credit facility, maximum borrowing capacity $ 300,000,000
Subsequent Event | Revolving Credit Facility | Senior secured credit facility
Subsequent Event [Line Items]
Credit facility, maximum borrowing capacity $ 650,000,000
Subsequent Event | Senior Notes | 8.000% senior unsecured notes due 2027
Subsequent Event [Line Items]
Debt issued $ 250,000,000
Debt premium percentage103.75%