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Published: 2021-11-04 12:42:02 ET

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2021

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 1-12295

GENESIS ENERGY, L.P.

(Exact name of registrant as specified in its charter)

Delaware

76-0513049

(State or other jurisdiction of
incorporation or organization)

(I.R.S. Employer
Identification No.)

919 Milam, Suite 2100,

Houston

77002

(Address of principal executive offices)

(Zip code)

Registrant’s telephone number, including area code:

(713)

860-2500


Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
Common units	GEL	NYSE

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ý No ¨

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Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ý

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date. There were 122,539,221 Class A Common Units and 39,997 Class B Common Units outstanding as of November 4, 2021.

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GENESIS ENERGY, L.P.

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		Page
	PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Unaudited Condensed Consolidated Balance Sheets	3
	Unaudited Condensed Consolidated Statements of Operations	4
	Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss)	5
	Unaudited Condensed Consolidated Statements of Partners’ Capital	6
	Unaudited Condensed Consolidated Statements of Cash Flows	7
	Notes to Unaudited Condensed Consolidated Financial Statements	8
	1. Organization and Basis of Presentation and Consolidation	8
	2. Recent Accounting Developments	9
	3. Revenue Recognition	9
	4. Lease Accounting	11
	5. Inventories	12
	6. Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations	13
	7. Equity Investees	14
	8. Intangible Assets	15
	9. Debt	16
	10. Partners' Capital, Mezzanine Capital and Distributions	18
	11. Net Loss Per Common Unit	21
	12. Business Segment Information	22
	13. Transactions with Related Parties	25
	14. Supplemental Cash Flow Information	26
	15. Derivatives	26
	16. Fair-Value Measurements	29
	17. Commitments and Contingencies	31

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	54
Item 4.	Controls and Procedures	54
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	55
Item 1A.	Risk Factors	55
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	55
Item 3.	Defaults upon Senior Securities	55
Item 4.	Mine Safety Disclosures	55
Item 5.	Other Information	55
Item 6.	Exhibits	56
SIGNATURES		57

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except units)


	September 30, 2021		December 31, 2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	10,407	$	21,282
Restricted cash	5,089		5,736
Accounts receivable - trade, net	321,637		392,465
Inventories	87,220		99,877

Other	57,330		60,809
Total current assets	481,683		580,169
FIXED ASSETS, at cost	5,385,516		5,173,475
Less: Accumulated depreciation	(1,494,832)		(1,322,141)
Net fixed assets	3,890,684		3,851,334
MINERAL LEASEHOLDS, net of accumulated depletion	550,000		552,575

EQUITY INVESTEES	296,202		319,068
INTANGIBLE ASSETS, net of amortization	127,148		128,742
GOODWILL	301,959		301,959
RIGHT OF USE ASSETS, net	140,027		153,925
OTHER ASSETS, net of amortization	38,623		45,847
TOTAL ASSETS	$	5,826,326	$	5,933,619
LIABILITIES AND CAPITAL
CURRENT LIABILITIES:
Accounts payable - trade	$	176,091	$	198,433
Accrued liabilities	202,028		184,978

Total current liabilities	378,119		383,411
SENIOR SECURED CREDIT FACILITY, net	430,577		643,700
SENIOR UNSECURED NOTES, net	2,929,000		2,750,016
DEFERRED TAX LIABILITIES	13,947		13,317
OTHER LONG-TERM LIABILITIES	420,881		393,018
Total liabilities	4,172,524		4,183,462

MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at September 30, 2021 and December 31, 2020	790,115		790,115
Redeemable noncontrolling interests, 246,394 and 141,249 preferred units issued and outstanding at September 30, 2021 and December 31, 2020, respectively	251,811		141,194

PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at September 30, 2021 and December 31, 2020	621,308		829,326
Accumulated other comprehensive loss	(9,000)		(9,365)
Noncontrolling interests	(432)		(1,113)
Total partners' capital	611,876		818,848
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$	5,826,326	$	5,933,619

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

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
REVENUES:
Offshore pipeline transportation	$	69,479	$	53,893	$	207,084	$	197,286
Sodium minerals and sulfur services	237,651		206,731		702,025		642,745
Marine transportation	48,716		51,912		136,673		170,978
Onshore facilities and transportation	162,975		130,589		498,113		360,506
Total revenues	518,821		443,125		1,543,895		1,371,515
COSTS AND EXPENSES:
Onshore facilities and transportation product costs	129,498		103,245		414,933		258,644
Onshore facilities and transportation operating costs	15,792		16,984		47,887		53,470
Marine transportation operating costs	39,782		36,342		111,986		117,840
Sodium minerals and sulfur services operating costs	196,656		178,688		578,058		550,931
Offshore pipeline transportation operating costs	21,080		21,698		63,060		56,762
General and administrative	14,371		11,072		38,944		45,858
Depreciation, depletion and amortization	67,148		67,733		200,975		222,210
Impairment expense	—		3,331		—		280,826
Total costs and expenses	484,327		439,093		1,455,843		1,586,541
OPERATING INCOME (LOSS)	34,494		4,032		88,052		(215,026)
Equity in earnings of equity investees	10,301		14,439		45,183		41,216
Interest expense	(59,940)		(51,312)		(176,938)		(157,895)
Other income (expense)	1,741		7,406		(34,169)		13,114
Loss from operations before income taxes	(13,404)		(25,435)		(77,872)		(318,591)
Income tax expense	(423)		(145)		(1,170)		(575)


NET LOSS	(13,827)		(25,580)		(79,042)		(319,166)
Net loss (income) attributable to noncontrolling interests	10		12		(124)		38
Net income attributable to redeemable noncontrolling interests	(7,082)		(4,149)		(17,639)		(12,394)
NET LOSS ATTRIBUTABLE TO GENESIS ENERGY, L.P.	$	(20,899)	$	(29,717)	$	(96,805)	$	(331,522)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
NET LOSS AVAILABLE TO COMMON UNITHOLDERS	$	(39,583)	$	(48,401)	$	(152,857)	$	(387,574)
NET LOSS PER COMMON UNIT (Note 11):


Basic and Diluted	$	(0.32)	$	(0.39)	$	(1.25)	$	(3.16)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted	122,579		122,579		122,579		122,579

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

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net loss	$	(13,827)	$	(25,580)	$	(79,042)	$	(319,166)
Other comprehensive income:
Amortization of prior service cost	122		122		365		365
Total Comprehensive loss	(13,705)		(25,458)		(78,677)		(318,801)
Comprehensive loss (income) attributable to noncontrolling interests	10		12		(124)		38
Comprehensive income attributable to redeemable noncontrolling interests	(7,082)		(4,149)		(17,639)		(12,394)
Comprehensive loss attributable to Genesis Energy, L.P.	$	(20,777)	$	(29,595)	$	(96,440)	$	(331,157)

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

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(In thousands)


	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners' capital, June 30, 2021	122,579	$	679,278	$	(594)	$	(9,122)	$	669,562
Net loss	—	(20,899)		(10)		—		(20,909)
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash contributions from noncontrolling interests	—	—		172		—		172
Other comprehensive income	—	—		—		122		122
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)


Partners' capital, September 30, 2021	122,579	$	621,308	$	(432)	$	(9,000)	$	611,876
	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners' capital, June 30, 2020	122,579	$	1,018,342	$	(1,900)	$	(8,188)	$	1,008,254
Net loss	—	(29,717)		(12)		—		(29,729)
Cash distributions to partners	—	(18,387)		—		—		(18,387)
Cash contributions from noncontrolling interests	—	—		319		—		319
Other comprehensive income	—	—		—		122		122
Distributions to Class A Convertible Preferred unitholders	—	(18,684)		—		—		(18,684)
Partners' capital, September 30, 2020	122,579	$	951,554	$	(1,593)	$	(8,066)	$	941,895


	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2020	122,579	$	829,326	$	(1,113)	$	(9,365)	$	818,848


Net income (loss)	—	(96,805)		124		—		(96,681)

Cash distributions to partners	—	(55,161)		—		—		(55,161)
Cash contributions from noncontrolling interests	—	—		557		—		557

Other comprehensive income	—	—		—		365		365
Distributions to Class A Convertible Preferred unitholders	—	(56,052)		—		—		(56,052)


Partners' capital, September 30, 2021	122,579	$	621,308	$	(432)	$	(9,000)	$	611,876
	Number of Common Units	Partners’ Capital		Noncontrolling Interest		Accumulated Other Comprehensive Loss		Total
Partners’ capital, December 31, 2019	122,579	$	1,443,320	$	(3,718)	$	(8,431)	$	1,431,171
Net loss	—	(331,522)		(38)		—		(331,560)

Cash distributions to partners	—	(104,192)		—		—		(104,192)
Cash contributions from noncontrolling interests	—	—		2,163		—		2,163

Other comprehensive income	—	—		—		365		365
Distributions to Class A Convertible Preferred unitholders	—	(56,052)		—		—		(56,052)

Partners' capital, September 30, 2020	122,579	$	951,554	$	(1,593)	$	(8,066)	$	941,895

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

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GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)


	Nine Months Ended September 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(79,042)	$	(319,166)
Adjustments to reconcile net loss to net cash provided by operating activities -
Depreciation, depletion and amortization	200,975		222,210

Impairment expense	—		280,826
Amortization and write-off of debt issuance costs, premium and discount	9,242		17,515
Amortization of non-cash costs on previously owned direct financing leases	—		(8,217)
Payments received under previously owned direct financing leases (Note 4)	52,500		56,837
Equity in earnings of investments in equity investees	(45,183)		(41,216)
Cash distributions of earnings of equity investees	44,747		40,773
Non-cash effect of long-term incentive compensation plans	5,111		(2,806)
Deferred and other tax liabilities	630		25
Unrealized losses (gains) on derivative transactions	30,729		(19,582)
Cancellation of debt income	—		(20,534)
Other, net	16,191		16,817
Net changes in components of operating assets and liabilities (Note 14)	6,457		72,146
Net cash provided by operating activities	242,357		295,628
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(217,972)		(100,381)
Cash distributions received from equity investees - return of investment	24,126		14,943
Investments in equity investees	(129)		—


Proceeds from asset sales	223		447

Net cash used in investing activities	(193,752)		(84,991)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	553,100		814,100
Repayments on senior secured credit facility	(763,800)		(788,600)
Proceeds from issuance of senior unsecured notes (Note 9)	259,375		750,000
Net proceeds from issuance of preferred units (Note 10)	93,100		—
Repayment of senior unsecured notes (Note 9)	(80,859)		(827,031)
Debt issuance costs	(12,208)		(15,279)

Contributions from noncontrolling interests	557		2,163
Distributions to common unitholders	(55,161)		(104,192)
Distributions to preferred unitholders	(56,052)		(56,052)
Other, net	1,821		1,865
Net cash used in financing activities	(60,127)		(223,026)
Net decrease in cash, restricted cash, and cash equivalents	(11,522)		(12,389)
Cash, restricted cash and cash equivalents at beginning of period	27,018		56,405
Cash, restricted cash and cash equivalents at end of period	$	15,496	$	44,016

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

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Organization and Basis of Presentation and Consolidation

Organization

We are a growth-oriented master limited partnership 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 the selling of the related by-product, sodium hydrosulfide (or "NaHS", commonly pronounced "nash");

•Onshore facilities and transportation, which include the terminalling, blending, storing, marketing and transporting of 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. Our operations, which fall within the energy, mining and transportation sectors, are considered critical and essential by the Department of Homeland Security's CISA and we have continued to operate our assets during this pandemic.

We have a designated internal management team to provide resources, updates, and support to our entire workforce during this pandemic, while maintaining a focus to ensure safety and well-being of our employees, the families of our employees, and the communities in which our businesses operate. We will continue to operate in the best interests of our employees, stakeholders, customers, partners, and suppliers and make any necessary changes as required by federal, state, or local authorities as we continue to actively monitor the situation.

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Beginning in March 2020, Covid-19 has caused continued volatility in commodity prices due to, among other things, reduced industrial activity and travel demand, varying worldwide restrictions, and the timing of the re-opening of economies. Additionally, actions taken by OPEC and other oil exporting nations in that timeframe caused additional volatility in the price of oil and gas. 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 deteriorate, we may identify triggering events that may require future evaluations of the recoverability of the carrying value of our long-lived assets, intangible assets and goodwill, which could result in impairment charges that could be material to our results of operations.

2. Recent Accounting Developments

Recently 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 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.

3. Revenue Recognition

Revenue from Contracts with Customers

The following tables reflect the disaggregation of our revenues by major category for the three months ended September 30, 2021 and 2020, respectively:


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


	Three Months Ended September 30, 2020
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities and Transportation		Consolidated
Fee-based revenues	$	53,893	$	—	$	51,912	$	22,406	$	128,211
Product Sales	—		188,201		—		108,183		296,384
Refinery Services	—		18,530		—		—		18,530
	$	53,893	$	206,731	$	51,912	$	130,589	$	443,125

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following tables reflect the disaggregation of our revenues by major category for the nine months ended September 30, 2021 and 2020, respectively:


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


	Nine Months Ended September 30, 2020
	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Marine Transportation		Onshore Facilities & Transportation		Consolidated
Fee-based revenues	$	197,286	$	—	$	170,978	$	85,241	$	453,505
Product Sales	—		575,977		—		275,265		851,242
Refinery Services	—		66,768		—		—		66,768
	$	197,286	$	642,745	$	170,978	$	360,506	$	1,371,515

The Company recognizes revenue upon the satisfaction of its performance obligations under its contracts. The timing of revenue recognition varies for our different revenue streams. In general, the timing includes recognition of revenue over time as services are being performed as well as recognition of revenue at a point in time, for delivery of products. During the three and nine months ended September 30, 2021, we recorded immaterial amounts of revenue associated with prior periods of approximately $10.7 million and $8.2 million, respectively, of which the majority was noncash.

Contract Assets and Liabilities

The table below depicts our contract asset and liability balances at December 31, 2020 and September 30, 2021:


	Contract Assets				Contract Liabilities
	Current Assets- Other		Other Assets		Accrued Liabilities		Other Long-Term Liabilities
Balance at December 31, 2020	$	36,500	$	12,065	$	2,988	$	19,834
Balance at September 30, 2021	22,374		—		2,856		19,620

Transaction Price Allocations to Remaining Performance Obligations

We are required to disclose the amount of our transaction prices that are allocated to unsatisfied performance obligations as of September 30, 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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	$	15,151	$	4,802
2022	75,623		4,698
2023	63,982		—
2024	56,326		—
2025	60,311		—
Thereafter	97,761		—
Total	$	369,154	$	9,500

4. Lease 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 assets and associated lease liabilities. 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 cease-use provision for railcars no longer in use. Our short-term and long-term lease liabilities are recorded within "Accrued liabilities" and "Other long-term liabilities," respectively, on our Unaudited Condensed Consolidated Balance Sheets.

Lessor Arrangements

We have the following contracts in which we act as a lessor. We also, from time to time, sublease certain of our transportation and facilities equipment to third parties.

Operating Leases

During the three and nine months ended September 30, 2021 and 2020, 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 three and nine months ended September 30, 2020, we acted as a lessor in our Free State pipeline system, which was included in our onshore facilities and transportation segment. Our lease revenues for these arrangements (inclusive of fixed and variable consideration) are reflected in the table below:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
M/T American Phoenix	$	4,140	$	6,787	$	11,379	$	20,164
Free State Pipeline (1)	—		1,467		—		4,889

(1) We sold the Free State pipeline to a subsidiary of Denbury, Inc. ("Denbury") on October 30, 2020.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 nine months ended September 30, 2021, we collected three payments totaling $52.5 million and we have an outstanding receivable (included within "Accounts receivable- trade, net" on the Unaudited Condensed Consolidated Balance Sheet) of $17.5 million as of September 30, 2021 from Denbury for the final payment due in the fourth quarter of 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.

5. Inventories

The major components of inventories were as follows:


	September 30, 2021		December 31, 2020
Petroleum products	$	14,941	$	5,840
Crude oil	14,268		37,661
Caustic soda	3,243		5,167
NaHS	14,140		9,101
Raw materials - Alkali operations	7,222		7,120
Work-in-process - Alkali operations	7,191		9,355
Finished goods, net - Alkali operations	12,877		13,002
Materials and supplies, net - Alkali operations	13,338		12,631

Total	$	87,220	$	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 $0.7 million and $5.0 million as of September 30, 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

6. Fixed Assets, Mineral Leaseholds, and Asset Retirement Obligations

Fixed Assets

Fixed assets, net consisted of the following:


	September 30, 2021		December 31, 2020
Crude oil and natural gas pipelines and related assets	$	2,841,150	$	2,811,030
Alkali facilities, machinery, and equipment	648,326		622,598
Onshore facilities, machinery, and equipment	269,301		267,810
Transportation equipment	21,422		19,470
Marine vessels	1,015,794		998,553
Land, buildings and improvements	222,215		219,382
Office equipment, furniture and fixtures	22,519		22,001
Construction in progress	301,349		170,740
Other	43,440		41,891
Fixed assets, at cost	5,385,516		5,173,475
Less: Accumulated depreciation	(1,494,832)		(1,322,141)
Net fixed assets	$	3,890,684	$	3,851,334

Mineral Leaseholds

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


	September 30, 2021		December 31, 2020
Mineral leaseholds	$	566,019	$	566,019
Less: Accumulated depletion	(16,019)		(13,444)
Mineral leaseholds, net of accumulated depletion	$	550,000	$	552,575

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Depreciation expense	$	63,482	$	62,499	$	190,332	$	206,830
Depletion expense	959		604		2,575		2,408

During the second quarter of 2020, due to the challenging economic environment from the decline in commodity prices (including the collapse in the differential of Western Canadian Select to the Gulf Coast) and Covid-19, crude-by-rail transportation became uneconomic for producers and the demand and outlook for our rail logistics assets declined. As a result, we recognized impairment expense of $277.5 million associated with the rail logistics assets in our onshore facilities and transportation segment, including $272.7 million of net fixed assets and $4.8 million of right of use assets, net on the Unaudited Condensed Consolidated Balance Sheet. The fair value was calculated utilizing the income approach and assumptions were primarily based on level 3 inputs of the fair value hierarchy.

In addition to this, we recognized impairment expense of $3.3 million during the three and nine months ended September 30, 2020 primarily associated with the full write-off of a non-core gas platform in our offshore transportation segment due to it not having a future use for our operations.

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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table presents information regarding our AROs since December 31, 2020:


ARO liability balance, December 31, 2020	$	176,852
Accretion expense	7,698
Changes in estimate	97


Settlements	(3,933)

ARO liability balance, September 30, 2021	$	180,714

Of the ARO balances disclosed above, $11.3 million and $14.7 million is included as current in "Accrued liabilities" on our Unaudited Condensed Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. The remainder of the ARO liability as of September 30, 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	$	2,390
	2022	$	9,384
	2023	$	9,128
	2024	$	9,783
	2025	$	10,487

Certain of our unconsolidated affiliates have AROs recorded at September 30, 2021 relating to contractual agreements and regulatory requirements. These amounts are immaterial to our Unaudited Condensed Consolidated Financial Statements.

7. Equity Investees

We account for our ownership in our joint ventures under the equity method of accounting. The price we pay to acquire an ownership interest in a company may exceed or be less than the underlying book value of the capital accounts we acquire. Such excess cost amounts are included within the carrying values of our equity investees. At September 30, 2021 and December 31, 2020, the unamortized excess cost amounts totaled $323.8 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 September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Genesis’ share of operating earnings	$	14,174	$	18,312	$	56,801	$	52,834
Amortization of excess purchase price	(3,873)		(3,873)		(11,618)		(11,618)
Net equity in earnings	$	10,301	$	14,439	$	45,183	$	41,216
Distributions received (1)	$	17,443	$	16,757	$	68,873	$	55,716

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

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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):


	September 30, 2021		December 31, 2020
BALANCE SHEET DATA:
Assets
Current assets	$	22,890	$	30,465
Fixed assets, net	164,096		171,732
Other assets	5,762		4,673
Total assets	$	192,748	$	206,870
Liabilities and equity
Current liabilities	$	12,001	$	9,958
Other liabilities	237,507		237,595
Equity (Deficit)	(56,760)		(40,683)
Total liabilities and equity	$	192,748	$	206,870


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
INCOME STATEMENT DATA:
Revenues	$	27,262	$	35,351	$	103,432	$	98,662
Operating income	$	18,762	$	27,002	$	75,559	$	72,530
Net income	$	17,718	$	25,831	$	72,473	$	68,050

Poseidon's Revolving Credit Facility

Borrowings under Poseidon’s revolving credit facility, which was amended and restated in March 2019, are primarily used to fund spending on capital projects. The March 2019 credit facility is non-recourse to Poseidon’s owners and secured by substantially all of Poseidon's assets and has a maturity date of March 2024. The March 2019 credit facility contains customary covenants such as restrictions on debt levels, liens, guarantees, mergers, sale of assets and distributions to owners. A breach of any of these covenants could result in acceleration of the maturity date of Poseidon’s debt. Poseidon was in compliance with the terms of its credit agreement for all periods presented in these Unaudited Condensed Consolidated Financial Statements.

8. Intangible Assets

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


	September 30, 2021						December 31, 2020
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Marine contract intangibles	$	800	$	599	$	201	$	800	$	571	$	229
Offshore pipeline contract intangibles	158,101		51,313		106,788		158,101		45,073		113,028
Other	35,401		15,242		20,159		29,244		13,759		15,485
Total	$	194,302	$	67,154	$	127,148	$	188,145	$	59,403	$	128,742

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Amortization of intangible assets	$	2,575	$	4,555	$	7,755	$	12,817

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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


Remainder of	2021	$	2,874
	2022	$	11,421
	2023	$	11,153
	2024	$	10,838
	2025	$	10,684

9. Debt

Our obligations under debt arrangements consisted of the following:


	September 30, 2021						December 31, 2020
	Principal		Unamortized Premium and Debt Issuance Costs		Net Value		Principal		Unamortized Debt Issuance Costs		Net Value
Senior secured credit facility-Revolving Loan (1)	$	133,000	$	—	$	133,000	$	643,700	$	—	$	643,700
Senior secured credit facility-Term Loan (2)	300,000		2,423		297,577		—		—		—
6.000% senior unsecured notes due 2023	—		—		—		80,859		504		80,355
5.625% senior unsecured notes due 2024	341,135		2,320		338,815		341,135		2,963		338,172
6.500% senior unsecured notes due 2025	534,834		4,749		530,085		534,834		5,639		529,195
6.250% senior unsecured notes due 2026	359,799		3,605		356,194		359,799		4,189		355,610
8.000% senior unsecured notes due 2027	1,000,000		6,993		993,007		750,000		13,022		736,978
7.750% senior unsecured notes due 2028	720,975		10,076		710,899		720,975		11,269		709,706
Total long-term debt	$	3,389,743	$	30,166	$	3,359,577	$	3,431,302	$	37,586	$	3,393,716

(1) Unamortized debt issuance costs associated with our senior secured credit facility Revolving Loan, as defined below (included in Other Assets, net of amortization on the Unaudited Condensed Consolidated Balance Sheets), were $5.2 million and $5.8 million as of September 30, 2021 and December 31, 2020, respectively.

(2) Unamortized debt issuance costs associated with our senior secured credit facility Term Loan, as defined below (included in Senior Secured Credit Facility, net on the Unaudited Condensed Consolidated Balance Sheets), was $2.4 million as of September 30, 2021.

Senior Secured Credit Facility

On April 8, 2021, we entered into the Fifth Amended and Restated Credit Agreement (our "new credit agreement") to replace our Fourth Amended and Restated Credit Agreement. Our new credit agreement provides for a $950 million senior secured credit facility, comprised of a revolving loan facility with a borrowing capacity of $650 million (the "Revolving Loan") and a term loan facility of $300 million (the "Term Loan"). The new credit agreement matures on March 15, 2024, subject to extension at our request for one additional year on up to two occasions and subject to certain conditions. At September 30, 2021, the key terms for rates under our Revolving Loan (which are dependent on our leverage ratio as defined in the new credit agreement) and Term Loan, are as follows:

•Revolving Loan: The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate is equal to the sum of (a) the greatest of (i) the prime rate in effect on such day, (ii) the federal funds effective rate in effect on such day plus 0.5% of 1% and (iii) the LIBOR rate for a one-month maturity on such day plus 1% and (b) the applicable margin. The Eurodollar rate is equal to the sum of (a) the LIBOR rate for the applicable interest period multiplied by the statutory reserve rate and (b) the applicable margin. The applicable margin varies from 2.25% to 3.75% on Eurodollar borrowings and from 1.25% to 2.75% on alternate base rate borrowings, depending on our leverage ratio. Our leverage ratio is recalculated quarterly and in connection with each material acquisition. At September 30, 2021, the applicable margins on our borrowings were 2.50% for alternate base rate borrowings and 3.50% for Eurodollar rate borrowings based on our leverage ratio.

•Term Loan: The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate and the Eurodollar rates for our Term Loan are calculated consistent with

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

our Revolving Loan discussed above, and the applicable margin is fixed at 3.75% on Eurodollar borrowings and 2.75% on alternate base rate borrowings for the Term Loan.

•Letter of credit fee rates range from 2.25% to 3.75% based on our leverage ratio as computed under the credit facility and can fluctuate quarterly. At September 30, 2021, our letter of credit rate was 3.50%.

•We pay a commitment fee on the unused portion of the Revolving Loan. The commitment fee rates on the unused committed amount will range from 0.30% to 0.50% per annum depending on our leverage ratio. At September 30, 2021, our commitment fee rate on the unused committed amount was 0.50%.

•We have the ability to increase the aggregate size of the Revolving Loan by an additional $200 million, subject to lender consent and certain other customary conditions.

At September 30, 2021, we had $133.0 million outstanding under our Revolving Loan, with $31.7 million of the borrowed amount designated as a loan under the inventory sublimit. Our new credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which $1.3 million was outstanding at September 30, 2021. Due to the revolving nature of loans under our Revolving Loan, additional borrowings, periodic repayments and re-borrowings may be made until the maturity date. The total amount available for borrowings under our Revolving Loan at September 30, 2021 was $515.7 million, subject to compliance with covenants.

At September 30, 2021, we had $300 million borrowed under our Term Loan. Principal repayments on the Term Loan under our new credit agreement are as follows (in thousands):


Year	Principal Due (1)
2021	$	15,000
2022	60,000
2023	100,000
2024	125,000

(1) Principal repayments of $15 million are due at the end of each calendar quarter starting December 31, 2021 until December 31, 2022. Principal repayments of $25 million are due at the end of each calendar quarter during 2023, with the remaining balance due at the maturity date of March 15, 2024. We intend to make the scheduled repayments on our Term Loan with the available borrowing capacity under our Revolving Loan.

Under our new credit agreement, the permitted maximum consolidated leverage ratio is 5.75x through March 31, 2022, and then 5.50x thereafter. The permitted maximum consolidated senior secured leverage ratio is 2.50x, and the minimum interest coverage ratio is 2.50x for the full term of the agreement. As of September 30, 2021, we were in compliance with the financial covenants contained in our new credit agreement and indentures for our senior unsecured notes as described below.

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 1, 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 the 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 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 nine months ended September 30, 2020.

On December 17, 2020, we issued $750 million in aggregate principal amount of our 8.00% senior unsecured notes due January 15, 2027 (the "2027 Notes"). Interest payments are due on January 15 and July 15 of each year with the initial interest payment due on July 15, 2021. The issuance generated net proceeds of approximately $737 million, net of issuance costs incurred. We used $316.5 million of the net proceeds to repay the portion of the 6.00% senior unsecured notes due May 15, 2023 (the "2023 Notes") (including principal, accrued interest and tender premium) that were validly tendered, and the remaining proceeds were used to repay a portion of the borrowings outstanding under our revolving credit facility. On January 19, 2021, we redeemed the remaining principal balance outstanding on our 2023 Notes of $80.9 million in accordance with the terms and conditions of the indenture governing the 2023 Notes. We incurred a total loss of approximately $1.6 million relating to the extinguishment of our remaining 2023 Notes, inclusive of the redemption fee and the write-off of the related unamortized debt issuance costs, which is recorded in "Other income (expense)" in our Unaudited Condensed Consolidated Statements of Operations for the nine months ended September 30, 2021.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

On April 22, 2021, we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The notes constitute an additional issuance of our existing 2027 Notes that we issued on December 17, 2020 in an aggregate principal amount of $750 million. The additional $250 million of notes have identical terms as (other than with respect to the issue price) and constitute part of the same series of the 2027 Notes. The $250 million of the 2027 Notes were issued at a premium of 103.75% plus accrued interest from December 17, 2020. We used the net proceeds from the offering for general partnership purposes, including repaying a portion of the revolving borrowings outstanding under our new credit agreement.

During 2020, we repurchased certain of our senior unsecured notes on the open market and recorded cancellation of

debt income of $0.8 million and $20.5 million for the three and nine months ended September 30, 2020, respectively. These are

recorded within "Other income (expense)" in our Unaudited Consolidated Statements of Operations.

Our $2.9 billion aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.'s current and future 100% owned domestic subsidiaries (the "Guarantor Subsidiaries"), except the subsidiaries that hold our Alkali Business, Genesis Free State Pipeline, LLC, Genesis NEJD Pipeline, LLC, and certain other subsidiaries. The assets owned by Genesis Free State Pipeline, LLC were sold on October 30, 2020 and the ownership of Genesis NEJD Pipeline, LLC's pipeline was transferred in October 2020. Genesis NEJD Pipeline, LLC is 100% owned by Genesis Energy, L.P., the parent company. The remaining non-guarantor subsidiaries are owned by Genesis Crude Oil, L.P., a Guarantor Subsidiary. The Guarantor Subsidiaries largely own the assets that we use to operate our business other than our Alkali Business. As a general rule, the assets and credit of our unrestricted subsidiaries are not available to satisfy the debts of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries, and the liabilities of our unrestricted subsidiaries do not constitute obligations of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries 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").

10. Partners’ Capital, Mezzanine Capital and Distributions

At September 30, 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 Amount		Total Amount
2020
1st Quarter	May 15, 2020		$	0.15	$	18,387
2nd Quarter	August 14, 2020		$	0.15	$	18,387
3rd Quarter	November 13, 2020		$	0.15	$	18,387
4th Quarter	February 12, 2021		$	0.15	$	18,387
2021
1st Quarter	May 14, 2021		$	0.15	$	18,387
2nd Quarter	August 13, 2021		$	0.15	$	18,387
3rd Quarter	November 12, 2021	(1)	$	0.15	$	18,387

(1) This distribution was declared on October 5, 2021 and will be paid to unitholders of record as of October 29, 2021.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Class A Convertible Preferred Units

At September 30, 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 Loss Attributable to Genesis Energy, L.P. is reduced by Class A Convertible Preferred Unit distributions that accumulated during the period. Net Loss Attributable to Genesis Energy, L.P. was reduced by $18.7 million and $56.1 million for the three and nine months ended September 30, 2021 and 2020.

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 Amount		Total Amount
2020
1st Quarter	May 15, 2020		$	0.7374	$	18,684
2nd Quarter	August 14, 2020		$	0.7374	$	18,684
3rd Quarter	November 13, 2020		$	0.7374	$	18,684
4th Quarter	February 12, 2021		$	0.7374	$	18,684
2021
1st Quarter	May 14, 2021		$	0.7374	$	18,684
2nd Quarter	August 13, 2021		$	0.7374	$	18,684
3rd Quarter	November 12, 2021	(1)	$	0.7374	$	18,684

(1) This distribution was declared on October 5, 2021 and will be paid to unitholders of record as of October 29, 2021.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Redeemable Noncontrolling Interests

On September 23, 2019, we, through a subsidiary, Alkali Holdings, entered into an amended and restated Limited Liability Company Agreement of Alkali Holdings (the "LLC Agreement") and a Securities Purchase Agreement (the "Securities Purchase Agreement") whereby certain investment fund entities affiliated with Blackstone Alternative Credit Advisors LP, formerly known as "GSO Capital Partners LP" (collectively "BXC") purchased $55,000,000 (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 (the "Granger Optimization Project" or "GOP"). BXC is obligated to purchase a minimum of $250,000,000 of preferred units of Alkali Holdings ("Minimum Alkali Holdings Preferred Units") unless certain customary closing conditions are not satisfied.

On April 14, 2020, we entered into an amendment to our agreements with BXC to, among other things, extend the construction timeline of the GOP by one year, which we currently anticipate completing in the second half of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to BXC, which was accounted for as issuance costs. As part of the amendment, the commitment period was increased to four years, and the total commitment of BXC was increased to, subject to compliance with the covenants contained in the agreements with BXC, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings and the Minimum Alkali Holdings Preferred Units was increased up to $251,750,000. As of September 30, 2021, there are 246,394 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 September 30, 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 Loss Attributable to Genesis Energy, L.P. for the three months ended September 30, 2021 includes $7.1 million of adjustments, of which $5.9 million was allocated to the paid-in-kind ("PIK") distributions on the outstanding Alkali Holdings preferred units and $1.2 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the nine months ended September 30, 2021 includes $17.7 million of adjustments, of which $14.9 million was allocated to the PIK distributions on the outstanding Alkali Holdings preferred units and $2.8 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the three months ended September 30, 2020 includes $4.2 million of adjustments, of which $3.5 million was allocated to the PIK distributions and $0.7 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the nine months ended September 30, 2020 includes $12.4 million of adjustments, of which $10.2 million was allocated to the PIK distributions and $2.2 million was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended September 30, 2021 in-kind to our Alkali Holdings preferred unitholders. The unitholders liquidation preference is increased by new issuances and PIK distributions and is reduced by tax distributions paid to the unitholders, which are required to be paid by us to fulfill the income tax liabilities of each holder of Alkali Holdings preferred units.

As of the reporting date, there are no triggering, change of control, early redemption or monetization events that are probable that would require us to revalue the Alkali Holdings preferred units.

If the Alkali Holdings preferred units were redeemed on the reporting date of September 30, 2021, the redemption amount would be equal to $289.9 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following table shows the change in our redeemable noncontrolling interest balance from December 31, 2020 to September 30, 2021:


Balance as of December 31, 2020	$	141,194
Issuance of preferred units, net of issuance costs (1)	103,042
PIK distribution	14,856
Redemption accretion	2,783
Tax distributions (1)	(10,064)
Balance as of September 30, 2021	$	251,811

(1) During the period ended September 30, 2021, we issued 10,145 Alkali Holdings preferred units to BXC to satisfy the company's obligation to pay tax distributions. Additionally, we issued 95,000 Alkali Holdings preferred units to BXC during the nine months ended September 30, 2021 to continue to fund the GOP.

11. Net 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 three and nine months ended September 30, 2021, the effect of the assumed conversion of the 25,336,778 Class A Convertible Preferred Units was anti-dilutive and was not included in the computation of diluted earnings per unit.

The following table reconciles net loss and weighted average units used in computing basic and diluted net loss per common unit (in thousands):


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net Loss Attributable to Genesis Energy L.P.	$	(20,899)	$	(29,717)	$	(96,805)	$	(331,522)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(18,684)		(18,684)		(56,052)		(56,052)
Net Loss Available to Common Unitholders	$	(39,583)	$	(48,401)	$	(152,857)	$	(387,574)

Weighted Average Outstanding Units	122,579		122,579		122,579		122,579

Basic and Diluted Net Loss per Common Unit	$	(0.32)	$	(0.39)	$	(1.25)	$	(3.16)

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

12. Business Segment Information

We currently manage our businesses through four divisions that constitute our reportable segments:

•Offshore pipeline transportation – offshore transportation of crude oil and natural gas in the Gulf of Mexico;

•Sodium minerals and sulfur services – trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as the processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur, and the selling of the related by-product, NaHS;

•Onshore facilities and transportation – terminalling, blending, storing, marketing and transporting crude oil and petroleum products (primarily fuel oil, asphalt, and other heavy refined products); and

•Marine transportation – marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America.

Substantially all of our revenues are derived from our assets that 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.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Segment information for the periods presented below was as follows:


	Offshore Pipeline Transportation		Sodium Minerals & Sulfur Services		Onshore Facilities & Transportation		Marine Transportation		Total
Three Months Ended September 30, 2021
Segment margin (a)	$	76,045	$	39,649	$	29,145	$	9,023	$	153,862
Capital expenditures (b)	$	3,819	$	67,583	$	929	$	6,886	$	79,217
Revenues:
External customers	$	69,479	$	240,048	$	161,296	$	47,998	$	518,821
Intersegment (c)	—		(2,397)		1,679		718		—
Total revenues of reportable segments	$	69,479	$	237,651	$	162,975	$	48,716	$	518,821
Three Months Ended September 30, 2020
Segment margin (a)	$	57,380	$	27,592	$	61,298	$	15,587	$	161,857
Capital expenditures (b)	$	2,899	$	19,225	$	1,446	$	5,273	$	28,843
Revenues:
External customers	$	53,870	$	208,909	$	130,440	$	49,906	$	443,125
Intersegment (c)	23		(2,178)		149		2,006		—
Total revenues of reportable segments	$	53,893	$	206,731	$	130,589	$	51,912	$	443,125
Nine Months Ended September 30, 2021
Segment Margin (a)	$	243,420	$	121,563	$	72,512	$	24,600	$	462,095
Capital expenditures (b)	$	34,768	$	158,181	$	4,515	$	29,757	$	227,221
Revenues:
External customers	$	207,084	$	708,612	$	493,852	$	134,347	$	1,543,895
Intersegment (c)	—		(6,587)		4,261		2,326		—
Total revenues of reportable segments	$	207,084	$	702,025	$	498,113	$	136,673	$	1,543,895
Nine Months Ended September 30, 2020
Segment Margin (a)	$	217,774	$	89,357	$	110,612	$	52,727	$	470,470
Capital expenditures (b)	$	5,909	$	67,662	$	3,432	$	22,998	$	100,001
Revenues:
External customers	$	197,263	$	648,987	$	361,929	$	163,336	$	1,371,515
Intersegment (c)	23		(6,242)		(1,423)		7,642		—
Total revenues of reportable segments	$	197,286	$	642,745	$	360,506	$	170,978	$	1,371,515

(a)A reconciliation of total Segment Margin to net 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.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Total assets by reportable segment were as follows:


	September 30, 2021		December 31, 2020
Offshore pipeline transportation	$	2,123,321	$	2,187,083
Sodium minerals and sulfur services	2,061,821		1,962,146
Onshore facilities and transportation	894,002		1,035,662
Marine transportation	703,669		711,058
Other assets	43,513		37,670
Total consolidated assets	$	5,826,326	$	5,933,619

Reconciliation of total Segment Margin to net loss attributable to Genesis Energy, L.P.:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Total Segment Margin	$	153,862	$	161,857	$	462,095	$	470,470
Corporate general and administrative expenses	(14,878)		(10,801)		(38,389)		(42,160)
Depreciation, depletion, amortization and accretion	(69,665)		(70,203)		(208,346)		(228,761)
Interest expense	(59,940)		(51,312)		(176,938)		(157,895)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)	(7,142)		(2,318)		(23,690)		(14,500)
Other non-cash items (2)	2,526		7,712		(30,601)		16,489
Distribution from unrestricted subsidiaries not included in income (3)	(17,500)		(44,088)		(52,500)		(48,620)
Cancellation of debt income (4)	—		809		—		20,534
Loss on extinguishment of debt (4)	—		—		(1,627)		(23,480)
Differences in timing of cash receipts for certain contractual arrangements (5)	(657)		(13,052)		(7,402)		(29,180)
Impairment expense (6)	—		(3,331)		—		(280,826)

Provision for leased items no longer in use	—		(696)		(598)		(624)
Redeemable noncontrolling interest redemption value adjustments (7)	(7,082)		(4,149)		(17,639)		(12,394)
Income tax expense	(423)		(145)		(1,170)		(575)
Net loss attributable to Genesis Energy, L.P.	$	(20,899)	$	(29,717)	$	(96,805)	$	(331,522)

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

(2) The three and nine months ended September 30, 2021 include a $1.7 million unrealized gain and $31.0 million unrealized loss, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and nine months ended September 30, 2020 include a $6.7 million unrealized gain and $17.4 million unrealized gain, respectively, from the valuation of the embedded derivative. Refer to Note 16 for details.

(3) The three and nine months ended September 30, 2021 include $17.5 million and $52.5 million, respectively, in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. The three and nine months ended September 30, 2020 include $44.1 million and $48.6 million, respectively, in cash receipts not included in income associated with principal repayments on our NEJD pipeline. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility. See Note 4 for details.

(4) Refer to Note 9 for details surrounding the repurchases of certain of our senior unsecured notes and the extinguishment of our 2022 Notes and 2023 Notes.

(5) Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts.

(6) Refer to Note 6 for details surrounding our non-cash impairment expense recorded for the three and nine months ended September 30, 2020.

(7) Includes PIK distributions attributable to the period and accretion on the redemption feature.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

13. Transactions with Related Parties

The transactions with related parties were as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Revenues:

Revenues from services and fees to Poseidon(1)	$	3,193	$	3,102	$	10,221	$	9,284
Revenues from product sales to ANSAC	61,651		44,095		200,935		165,869


Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft	$	165	$	165	$	495	$	495
Charges for services from Poseidon(1)	242		231		720		734
Charges for services from ANSAC	400		528		1,097		1,989

(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 automatically renews annually unless terminated by either party (as defined in the agreement). Our revenues for the three and nine months ended September 30, 2021 reflect $2.4 million and $7.1 million, respectively, associated with this agreement. Our revenues for the three and nine months ended September 30, 2020 reflect $2.3 million and $6.8 million, respectively, of fees we earned through the provision of services under that agreement. At September 30, 2021 and December 31, 2020, Poseidon owed us $3.3 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 September 30, 2021, such amount is not material to us.

Net Sales to ANSAC were $61.7 million and $200.9 million during the three and nine months ended September 30, 2021 and were $44.1 million and $165.9 million during the three and nine months ended September 30, 2020. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $0.4 million and $1.1 million during the three and nine months ended September 30, 2021 and were $0.5 million and $2.0 million during the three and nine months ended September 30, 2020.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Receivables from and payables to ANSAC as of September 30, 2021 and December 31, 2020 are as follows:


	September 30,		December 31,
	2021		2020
Receivables:
ANSAC	$	56,076	$	43,400
Payables:
ANSAC	$	400	$	470

14. Supplemental Cash Flow Information

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


	Nine Months Ended September 30,
	2021		2020
(Increase) decrease in:
Accounts receivable	$	15,487	$	165,505
Inventories	11,108		(24,674)
Deferred charges	20,362		17,616
Other current assets	(10,335)		(1,620)
Increase (decrease) in:
Accounts payable	(50,361)		(59,477)
Accrued liabilities	20,196		(25,204)
Net changes in components of operating assets and liabilities	$	6,457	$	72,146

Payments of interest and commitment fees were $154.4 million and $138.3 million for the nine months ended September 30, 2021 and September 30, 2020, respectively. We capitalized interest of $2.3 million and $1.4 million during the nine months ended September 30, 2021 and September 30, 2020, respectively.

At September 30, 2021 and September 30, 2020, we had incurred liabilities for fixed and intangible asset additions totaling $44.9 million and $26.5 million, respectively, that had not been paid at the end of the quarter, and, therefore, were not included in the caption “Payments to acquire fixed and intangible assets” under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows. The increase in this amount is principally due to the increase in capital expenditures associated with our GOP (Note 10).

15. Derivatives

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

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 September 30, 2021, we entered into the following outstanding derivative commodity contracts to economically hedge inventory, fixed price purchase commitments or forecasted purchases.


	Sell (Short) Contracts		Buy (Long) Contracts
Designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)	77		—
Weighted average contract price per bbl	$	70.29	$	—

Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)	320		116
Weighted average contract price per bbl	$	71.26	$	71.64
Natural gas swaps:
Contract volumes (10,000 MMBTU)	91		—
Weighted average price differential per MMBTU	$	0.09	$	—
Natural gas futures:
Contract volumes (10,000 MMBTU)	69		186
Weighted average contract price per MMBTU	$	5.83	$	4.42
NYM NYHBRULSD:
Contract volumes (42,000 gal)	43		—
Weighted average contract price per gallon	$	2.20	$	—
NYM RBOB Gas futures:
Contract volumes (42,000 gal)	97		—
Weighted average contract price per gallon	$	2.12	$	—



Crude oil options:
Contract volumes (1,000 bbls)	9		6
Weighted average premium received/paid	$	1.20	$	1.18

Financial Statement Impacts

Unrealized gains are subtracted from net income and unrealized losses are added to net income in determining cash flows from operating activities. To the extent that we have fair value hedges outstanding, the offsetting change recorded in the

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in 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 September 30, 2021 and December 31, 2020:

Fair Value of Derivative Assets and Liabilities


	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2021		December 31, 2020
Asset Derivatives:
Commodity derivatives - futures and call options (undesignated hedges):
Gross amount of recognized assets	Current Assets - Other	$	1,693	$	732
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(1,693)		(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	—		616
Commodity derivatives - futures and call options (designated hedges):
Gross amount of recognized assets	Current Assets - Other	$	180	$	1,022
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other	(180)		(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	(83,414)		(52,372)
Natural Gas Swap (undesignated hedge)	Current Liabilities -Accrued Liabilities	(55)		—
Commodity derivatives - futures and call options (undesignated hedges):
Gross amount of recognized liabilities	Current Assets - Other (1)	$	(3,315)	$	(2,114)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other (1)	3,315		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)	$	(499)	$	(3,345)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets	Current Assets - Other (1)	499		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

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 September 30, 2021, we had a net broker receivable of approximately $2.8 million (consisting of initial margin of $2.5 million increased by $0.3 million 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 September 30, 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 (expense)" in our Unaudited Condensed Consolidated Statement of Operations. At September 30, 2021, the fair value of this embedded derivative was a liability of $83.4 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 September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Onshore facilities and transportation product costs	$	(285)	$	(854)	$	(7,745)	$	(11,061)
Contracts not considered hedges under accounting guidance	Onshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs	(171)		1,175		(5,871)		(2,842)
Total commodity derivatives		$	(456)	$	321	$	(13,616)	$	(13,903)

Natural Gas Swap	Sodium minerals and sulfur services operating costs	$	(55)	$	666	$	(92)	$	1,217

Preferred Distribution Rate Reset Election	Other income (expense)	$	1,740	$	6,689	$	(31,042)	$	17,395

16. Fair-Value Measurements

We classify financial assets and liabilities into the following three levels based on the inputs used to measure fair value:

(1)Level 1 fair values are based on observable inputs such as quoted prices in active markets for identical assets and liabilities;

(2)Level 2 fair values are based on pricing inputs other than quoted prices in active markets for identical assets and liabilities and are either directly or indirectly observable as of the measurement date; and

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(3)Level 3 fair values are based on unobservable inputs in which little or no market data exists.

As required by fair value accounting guidance, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

Our assessment of the significance of a particular input to the fair value requires judgment and may affect the placement of assets and liabilities within the fair value hierarchy levels.

The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2021 and December 31, 2020.


	Fair Value at						Fair Value at
	September 30, 2021						December 31, 2020
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Commodity derivatives:
Assets	$	1,873	$	—	$	—	$	1,754	$	616	$	—
Liabilities	$	(3,814)	$	(55)	$	—	$	(5,459)	$	—	$	—
Preferred Distribution Rate Reset Election	$	—	$	—	$	(83,414)	$	—	$	—	$	(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:


	Nine Months Ended September 30,
	2021
Balance as of December 31, 2020	$	(52,372)
Unrealized loss for the period included in earnings	(31,042)

Balance as of September 30, 2021	$	(83,414)

Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy. The fair value of the swaps contracts was determined using market price quotations and a pricing model. The swap contracts were considered a level 2 input in the fair value hierarchy at September 30, 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, the discount yield (which is adjusted periodically for changes associated with the industry's credit markets), 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 September 30, 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 an increase in our discount yield compared to the preceding quarter, we recorded an unrealized gain of $1.7 million for the three months ended September 30, 2021. However, an overall decrease in our discount yield compared to December 31, 2020, as well as the passage of time as we draw nearer to our coupon rate reset date in 2022, resulted in an unrealized loss of $31.0 million for the nine months ended September 30, 2021. During the third quarter of 2020, we recorded an unrealized gain of $6.7 million, and for the nine months ended September 30, 2020, we recorded an unrealized gain of $17.4 million, due to changes in our discount yield as a result of significant fluctuations in the energy industry credit markets and volatility in our common unit price during the period. These effects are all recorded within "Other income (expense)" on the Unaudited Condensed Consolidated Statements of Operations.

See Note 15 for additional information on our derivative instruments.

Other Fair Value Measurements

We believe the debt outstanding under our credit facility approximates fair value as the stated rate of interest approximates current market rates of interest for similar instruments with comparable maturities. At September 30, 2021 our senior unsecured notes had a carrying value and fair value of $2.9 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.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

17. Commitments and Contingencies

We are subject to various environmental laws and regulations. Policies and procedures are in place to aid in monitoring compliance and detecting and addressing releases of crude oil from our pipelines or other facilities and from our mining operations relating to our Alkali Business; however, no assurance can be made that such environmental releases may not substantially affect our business.

We are subject to lawsuits in the normal course of business and examination by tax and other regulatory authorities. We do not expect such matters presently pending to have a material effect on our financial position, results of operations, or cash flows.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following information should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and accompanying notes included in this Quarterly Report on Form 10-Q. The following information and such Unaudited Condensed Consolidated Financial Statements should also be read in conjunction with the audited financial statements and related notes, together with our discussion and analysis of financial position and results of operations, included in our Annual Report.

Included in Management’s Discussion and Analysis of Financial Condition and Results of Operations are the following sections:

•Overview

•Results of Operations

•Liquidity and Capital Resources

•Guarantor Summarized Financial Information

•Non-GAAP Financial Measures

•Commitments and Off-Balance Sheet Arrangements

•Forward Looking Statements

Overview

We reported Net Loss Attributable to Genesis Energy, L.P. of $20.9 million during the three months ended September 30, 2021 (the "2021 Quarter") compared to Net Loss Attributable to Genesis Energy, L.P. of $29.7 million during the three months ended September 30, 2020 (the "2020 Quarter").

Net Loss Attributable to Genesis Energy, L.P. in the 2021 Quarter was impacted, relative to the 2020 Quarter, by: (i) an increase in operating income associated with our offshore pipeline transportation and sodium minerals and sulfur services segments due to higher volumes and corresponding revenue during the 2021 Quarter (see "Results of Operations" below for additional details) and (ii) lower impairment expense of $3.3 million as the 2020 Quarter included a write-off of one of our non-core offshore gas platforms. These increases were offset by: (i) higher interest expense of $8.6 million during the 2021 Quarter; (ii) an unrealized (non-cash) gain from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units of $1.7 million in the 2021 Quarter compared to an unrealized (non-cash) gain of $6.7 million during the 2020 Quarter recorded within Other income (expense); (iii) lower equity in earnings of equity investees by approximately $4.1 million; and (iv) higher general and administrative costs by $3.3 million during the 2021 Quarter.

Cash flow from operating activities was $54.2 million for the 2021 Quarter compared to $143.5 million for the 2020 Quarter. This decrease is primarily attributable to higher cash payments received under our previously owned direct financing lease in the 2020 Quarter and changes in working capital amongst the two periods.

Available Cash before Reserves (as defined below in "Non-GAAP Financial Measures") to our common unitholders was $48.2 million for the 2021 Quarter, a decrease of $22.5 million, or 32%, from the 2020 Quarter. See “Non-GAAP Financial Measures” below for additional information on Available Cash before Reserves.

Segment Margin (as defined below in "Non-GAAP Financial Measures") was $153.9 million for the 2021 Quarter, a decrease of $8.0 million, or 5%, from the 2020 Quarter. A more detailed discussion of our segment results and other costs are included below in "Results of Operations".

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

Distribution

In October 2021, we declared our quarterly distribution to our common unitholders of $0.15 per unit related to the 2021 Quarter. With respect to our Class A Convertible Preferred Units, we declared a quarterly cash distribution of $0.7374 per Class A Convertible Preferred Unit (or $2.9496 on an annualized basis) for each Class A Convertible Preferred Unit held of record. These distributions will be payable on November 12, 2021 to unitholders of record at the close of business on October 29, 2021.

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Covid-19 and Market Update

We have a designated internal management team to provide resources, updates, and support to our entire workforce during this pandemic, while maintaining a focus to ensure the safety and well-being of our employees, the families of our employees, and the communities in which our businesses operate. We will continue to act in the best interests of our employees, stakeholders, customers, partners, and suppliers and make any necessary changes as required by federal, state, or local authorities as we continue to actively monitor the situation.

Due to the economic effects from commodity prices and Covid-19, demand and volumes throughout our businesses were negatively impacted beginning in the second quarter of 2020. Additionally, during 2020, our businesses were negatively impacted by lower refinery utilization, crude differentials, supply and demand imbalances in our Alkali Business, and an unprecedented hurricane season. However, we began to see economic recovery across a majority of our asset footprint as we exited 2020, which has continued during 2021. Specifically, during 2021, our offshore pipeline transportation segment experienced volumes at its normal run rate as we resumed normal operations on our CHOPS pipeline. Additionally, our Alkali Business has continued to see volume demand recovery and continued pricing recovery on our ANSAC export volumes.

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 deteriorate, we may identify triggering events that may require future evaluations of the recoverability of the carrying value of our long-lived assets, intangible assets and goodwill, which could result in impairment charges that could be material to our results of operations.

We believe the fundamentals of our core businesses continue to remain strong and, given the current industry environment and capital market behavior, we have continued our focus on de-leveraging our balance sheet, which included the reduction of our distribution to common unitholders beginning in the first quarter of 2020 and continuing to recognize the benefits from our cost savings initiative implemented in the second quarter of 2020. Additionally, during 2021, we successfully refinanced and extended our senior secured credit facility and issued an additional $250 million in aggregate principal amount of our 2027 Notes. These two events resulted in no scheduled maturities of long-term debt until 2024, other than the minimal quarterly payments due on the Term Loan under our new credit agreement beginning at the end of 2021 (which will be financed by the available borrowing capacity under the Revolving Loan under our new credit agreement). Refer to "Liquidity and Capital Resources" for additional discussion.

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Results of Operations

Revenues and Costs and Expenses

Our revenues for the 2021 Quarter increased $75.7 million, or 17%, from the 2020 Quarter and our total costs and expenses (excluding impairment expense) as presented on the Unaudited Condensed Consolidated Statements of Operations increased $48.6 million, or 11%, between the two periods, with an increase to our operating income of $27.1 million. The increase in our operating income during the 2021 Quarter is primarily driven by increased volumes and revenues within our offshore pipeline transportation segment and increased soda ash volumes and pricing within our sodium minerals and sulfur services segment.

A substantial portion of our revenues and costs are derived from the purchase and sale of crude oil in our crude oil marketing business, which is included in our onshore facilities and transportation segment, and revenues and costs associated with our Alkali Business, which is included in our sodium minerals and sulfur services segment. We describe, in more detail, the impact on revenues and costs for each of our businesses below.

As it relates to our crude oil marketing business, the average closing prices for West Texas Intermediate crude oil on the New York Mercantile Exchange ("NYMEX") increased to $70.56 per barrel in the 2021 Quarter, as compared to $40.93 per barrel in the 2020 Quarter. We would expect changes in crude oil prices to continue to proportionately affect our revenues and costs attributable to our purchase and sale of crude oil and petroleum products, producing minimal direct impact on Segment Margin, net income(loss), and Available Cash before Reserves. We have limited our direct commodity price exposure related to crude oil and petroleum products through the broad use of fee-based service contracts, back-to-back purchase and sale arrangements, and hedges. As a result, changes in the price of crude oil would proportionately impact both our revenues and our costs, with a disproportionately smaller net impact on our Segment Margin. However, we do have some indirect exposure to certain changes in prices for oil, natural gas, and petroleum products, particularly if they are significant and extended. We tend to experience more demand for certain of our services when commodity prices increase significantly over extended periods of time, and we tend to experience less demand for certain of our services when commodity prices decrease significantly over extended periods of time. For additional information regarding certain of our indirect exposure to commodity prices, see our segment-by-segment analysis below and the section of our Annual Report entitled " Risks Related to Our Business."

As it relates to our Alkali Business, our revenues are derived from the extraction of trona, as well as the activities surrounding the processing and sale of natural soda ash and other alkali specialty products, including sodium sesquicarbonate (S-Carb) and sodium bicarbonate (Bicarb), and are a function of our selling prices and volume sold. We sell our products to an industry-diverse and worldwide customer base. Our selling prices are contracted at various times throughout the year and for different durations. Our selling prices for volumes sold internationally and through ANSAC are contracted for the current year either annually in the prior year or periodically throughout the current year (often quarterly), and our volumes priced and sold domestically are contracted at various times and can be of varying durations, often multi-year terms. Our sales volumes can fluctuate from period to period and are dependent upon many factors, of which the main drivers are the global market, customer demand and economic growth. Positive or negative changes to our revenue, through fluctuations in sales volumes or selling prices, can have a direct impact to Segment Margin, net income and Available Cash before Reserves as these fluctuations may have a lesser impact to operating costs due to the fact that a portion of our costs are fixed in nature. Our costs, of which some are variable in nature and others are fixed in nature, relate primarily to the processing and producing of soda ash (and other alkali specialty products) and marketing and selling activities. In addition, costs include activities associated with mining and extracting trona ore, including energy costs and employee compensation. In our Alkali Business, during the 2021 Quarter as noted above, we had positive effects to our revenues (with a lesser impact to costs) relative to the 2020 Quarter due to increased sales volumes and more favorable ANSAC pricing. For additional information, see our segment-by-segment analysis below.

In addition to our crude oil marketing business and Alkali Business discussed above, we continue to operate in our other core businesses including: (i) our offshore Gulf of Mexico crude oil and natural gas pipeline transportation and handling operations, focusing on providing a suite of services primarily to integrated and large independent energy companies who make intensive capital investments (often in excess of a billion dollars) to develop numerous large-reservoir, long-lived crude oil and natural gas properties; (ii) our sulfur services business, which is one of the largest producers and marketers (based on tons produced) of NaHS in North and South America; and (iii) our onshore-based refinery-centric operations located primarily in the Gulf Coast region of the U.S., which focus on providing a suite of services primarily to refiners. Refiners are the shippers of over 95% of the volumes transported on our onshore crude pipelines, and refiners contract for over 80% of the use of our inland barges, which are used primarily to transport intermediate refined products (not crude oil) between refining complexes. The shippers on our offshore pipelines are mostly integrated and large independent energy companies whose production is ideally suited for the vast majority of refineries along the Gulf Coast, unlike the lighter crude oil and condensates produced from numerous onshore shale plays. Their large-reservoir properties and the related pipelines and other infrastructure needed to develop them are capital intensive and yet, we believe, economically viable, in most cases, even in relatively low commodity price environments. Given these facts, we do not expect changes in commodity prices to impact our net income, Available Cash before Reserves or Segment Margin derived from our offshore Gulf of Mexico crude oil and natural gas pipeline transportation

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and handling operations in the same manner in which they impact our revenues and costs derived from the purchase and sale of crude oil and petroleum products.

Additionally, changes in certain of our operating costs between the respective quarters, such as those associated with our sodium minerals and sulfur services, offshore pipeline and marine transportation segments, are not correlated with crude oil prices. We discuss certain of those costs in further detail below in our segment-by-segment analysis.

Segment Margin

The contribution of each of our segments to total Segment Margin was as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
Offshore pipeline transportation	$	76,045	$	57,380	$	243,420	$	217,774
Sodium minerals and sulfur services	39,649		27,592		121,563		89,357
Onshore facilities and transportation	29,145		61,298		72,512		110,612
Marine transportation	9,023		15,587		24,600		52,727
Total Segment Margin	$	153,862	$	161,857	$	462,095	$	470,470

We define Segment Margin as revenues less product costs, operating expenses, and segment general and administrative expenses, after eliminating gain or loss on sale of assets, plus or minus applicable Select Items. Although we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. See "Non-GAAP Financial Measures" for further discussion surrounding total Segment Margin.

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Total Segment Margin	$	153,862	$	161,857	$	462,095	$	470,470
Corporate general and administrative expenses	(14,878)		(10,801)		(38,389)		(42,160)
Depreciation, depletion, amortization and accretion	(69,665)		(70,203)		(208,346)		(228,761)
Interest expense	(59,940)		(51,312)		(176,938)		(157,895)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)	(7,142)		(2,318)		(23,690)		(14,500)
Other non-cash items (2)	2,526		7,712		(30,601)		16,489
Distribution from unrestricted subsidiaries not included in income (3)	(17,500)		(44,088)		(52,500)		(48,620)
Cancellation of debt income	—		809		—		20,534

Provision for leased items no longer in use	—		(696)		(598)		(624)
Differences in timing of cash receipts for certain contractual arrangements (4)	(657)		(13,052)		(7,402)		(29,180)

Loss on debt extinguishment (5)	—		—		(1,627)		(23,480)
Impairment expense	—		(3,331)		—		(280,826)
Redeemable noncontrolling interest redemption value adjustments (6)	(7,082)		(4,149)		(17,639)		(12,394)
Income tax expense	(423)		(145)		(1,170)		(575)
Net Loss Attributable to Genesis Energy, L.P.	$	(20,899)	$	(29,717)	$	(96,805)	$	(331,522)

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

(2)The three and nine months ended September 30, 2021 include a $1.7 million unrealized gain and a $31.0 million unrealized loss, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and nine months ended September 30, 2020 include a $6.7 million unrealized gain and $17.4 million unrealized gain, respectively, from the valuation of the embedded derivative.

(3)The three and nine months ended September 30,2021 include $17.5 million and $52.5 million, respectively, and the three and nine months ended September 30, 2020 include $44.1 million and $48.6 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.

(4)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. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

(5)The nine months ended September 30, 2021 includes the transaction costs and write-off of the unamortized issuance costs associated with the redemption of our remaining 2023 Notes. The nine months ended September 30, 2020 includes the transaction costs associated with the tender and redemption of our 2022 Notes, as well as the write-off of the unamortized issuance costs and discount associated with these notes.

(6) Includes PIK distributions attributable to the period and accretion on the redemption feature.

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Offshore Pipeline Transportation Segment

Operating results and volumetric data for our offshore pipeline transportation segment are presented below:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
Offshore crude oil pipeline revenue, excluding non-cash revenues	$	68,342	$	52,157	$	201,157	$	182,741
Offshore natural gas pipeline revenue, excluding non-cash revenues	8,878		8,166		29,842		31,805
Offshore pipeline operating costs, excluding non-cash expenses	(18,218)		(19,221)		(55,552)		(50,963)
Distributions from equity investments (1)	17,043		16,278		67,973		54,191
Offshore pipeline transportation Segment Margin	$	76,045	$	57,380	$	243,420	$	217,774

Volumetric Data 100% basis:
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS	211,809		98,626		178,083		178,962
Poseidon	208,593		274,008		270,641		268,862
Odyssey	94,171		84,902		119,100		117,100
GOPL (2)	7,169		1,266		7,532		3,706
Total crude oil offshore pipelines	521,742		458,802		575,356		568,630

Natural gas transportation volumes (MMBtus/d)	317,025		265,465		329,908		337,039

Volumetric Data net to our ownership interest (3):
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS	211,809		98,626		178,083		178,962
Poseidon	133,500		175,365		173,210		172,072
Odyssey	27,310		24,622		34,539		33,959
GOPL (2)	7,169		1,266		7,532		3,706
Total crude oil offshore pipelines	379,788		299,879		393,364		388,699

Natural gas transportation volumes (MMBtus/d)	100,418		83,833		103,863		112,501

(1)Offshore pipeline transportation Segment Margin includes distributions received from our offshore pipeline joint ventures accounted for under the equity method of accounting in 2021 and 2020, respectively.

(2)One of our wholly-owned subsidiaries (GEL Offshore Pipeline, LLC, or "GOPL") owns our undivided interest in the Eugene Island pipeline system.

(3)Volumes are the product of our effective ownership interest through the year, including changes in ownership interest, multiplied by the relevant throughput over the given year.

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Offshore pipeline transportation Segment Margin for the 2021 Quarter increased $18.7 million, or 33%, from the 2020 Quarter primarily due to higher crude oil and natural gas transportation volumes. During the 2020 Quarter, our offshore pipeline transportation segment experienced an unprecedented period of unplanned downtime and interruption from Hurricanes Laura and Marco as a result of producers shutting in and us taking the necessary safety precautions to remove all personnel from the platforms that we operate and maintain. As a result of these named storms, the majority of our assets were shut in for one to two weeks and our CHOPS pipeline was out of service beginning August 26, 2020 until it resumed service on February 4, 2021. Additionally, we incurred incremental operating expenses during the 2020 Quarter related to certain regulatory inspections and analyses performed to ensure our assets were safe to return to service. While we experienced downtime from Hurricane Ida during the 2021 Quarter, the impact to our results in the period was not as significant as the events during the 2020 Quarter. As it relates to Hurricane Ida, we did not experience any damage to our assets but we did experience longer than anticipated downtime during the quarter, primarily on our Poseidon pipeline which was a direct result of the lack of power at certain third-

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party facilities and gas processing limitations onshore. The financial impact from Poseidon being down for a part of September as a result of Hurricane Ida will impact the fourth quarter of 2021 as the distribution we receive during that period covers business activities on Poseidon from September through November.

Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Offshore pipeline transportation Segment Margin for the first nine months of 2021 increased $25.6 million, or 12%, from the first nine months of 2020, primarily as a result of: (i) the increased volumes transported on our 100% owned SEKCO pipeline as a result of increased production activity from the Buckskin and Lucius fields, which are fully dedicated to SEKCO and further downstream to Poseidon, and (ii) and the increased distributions received from our 64% investment in Poseidon. The increase in distributions received from Poseidon during 2021 is a result of both the increased SEKCO volumes and the diversion of barrels to Poseidon from our CHOPS pipeline during its out of service period.

Sodium Minerals and Sulfur Services Segment

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Volumes sold:
NaHS volumes (Dry short tons "DST")	27,873		28,105		84,727		80,129
Soda Ash volumes (short tons sold)	686,851		588,949		2,221,803		2,006,006
NaOH (caustic soda) volumes (DST)	22,456		20,922		63,842		57,551


Revenues (in thousands):
NaHS revenues, excluding non-cash revenues	$	32,631	$	29,271	$	92,901	$	85,788
NaOH (caustic soda) revenues	11,572		9,256		29,778		25,341
Revenues associated with Alkali Business	167,789		151,227		508,892		469,361
Other revenues	1,402		624		3,225		1,729
Total external segment revenues, excluding non-cash revenues(1)	$	213,394	$	190,378	$	634,796	$	582,219

Segment Margin (in thousands)	$	39,649	$	27,592	$	121,563	$	89,357

Average index price for NaOH per DST(2)	$	825	$	697	$	743	$	681

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

(2) Source: IHS Chemical.

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Sodium minerals and sulfur services Segment Margin for the 2021 Quarter increased $12.1 million, or 44%. This increase is primarily due to higher soda ash volumes and slightly favorable export pricing in our Alkali Business in the 2021 Quarter as compared to the 2020 Quarter. During the 2020 Quarter, volume demand in our Alkali Business was significantly impacted by the worldwide economic shutdowns and uncertainty from the Covid-19 pandemic. As economies have continued to open up and reduce restrictions, we have seen demand recovery, both domestically and internationally through ANSAC. We continued to produce at a high rate at our Westvaco facility during the 2021 Quarter. Additionally, we saw slightly favorable export pricing in the 2021 Quarter relative to the 2020 Quarter and sequentially from the first half of 2021, which is evidence that the supply and demand balance is becoming more aligned. In our refinery services business, our NaHS sales volumes remained relatively flat between the 2021 Quarter and 2020 Quarter as demand has continued to recover and return to its pre-pandemic levels over the last twelve months due to the re-opening of economies. NaHS revenues and Segment Margin contribution were higher in the 2021 Quarter due to favorable index pricing and economies of scale associated with the higher production at our largest host refinery in the 2021 Quarter.

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Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Sodium minerals and sulfur services Segment Margin for the first nine months of 2021 increased $32.2 million, or 36%, from the first nine months of 2020. This increase is primarily due to higher soda ash volumes and more favorable export pricing in our Alkali Business and higher NaHS sales volumes in our refinery services business during 2021. During 2020, volume demand in our Alkali Business was significantly impacted by the worldwide economic shutdowns and uncertainty from the Covid-19 pandemic. As economies have continued to open up and reduce restrictions, we have seen demand recovery, both domestically and internationally through ANSAC, and continued to produce at a high rate at our Westvaco facility during 2021. Additionally, relative to 2020, we benefited from slightly favorable export pricing in 2021. These increases were partially offset by lower domestic pricing and lower sales volumes associated with our Granger facility, as it was put in cold standby during the second half of 2020 and had no production during 2021. Our Granger facility is expected to come back online during the second half of 2023 upon the completion of the GOP. In our refinery services business, we reported higher NaHS volumes in 2021 primarily due to improved demand from our domestic pulp and paper customer base that was negatively impacted in 2020 as a result of the timing of spring turnarounds and outages due to the Covid-19 pandemic. This was partially offset by lower demand from our mining customers, primarily in Peru.

Onshore Facilities and Transportation Segment

Our onshore facilities and transportation segment utilizes an integrated set of pipelines and terminals, as well as trucks, railcars, and barges to facilitate the movement of crude oil and refined products on behalf of producers, refiners and other customers. This segment includes crude oil and refined products pipelines, terminals and rail facilities operating primarily within the United States Gulf Coast crude oil market. In addition, we utilize our trucking fleet that supports the purchase and sale of gathered and bulk purchased crude oil, as well as purchased and sold refined products. Through these assets we offer our customers a full suite of services, including the following:

•facilitating the transportation of crude oil from producers to refineries and from owned and third party terminals to refiners via pipelines;

•shipping crude oil and refined products to and from producers and refiners via trucks, pipelines, and railcars;

•unloading railcars at our crude-by-rail terminals;

•storing and blending of crude oil and intermediate and finished refined products;

•purchasing/selling and/or transporting crude oil from the wellhead to markets for ultimate use in refining; and

•purchasing products from refiners, transporting those products to one of our terminals and blending those products to a quality that meets the requirements of our customers and selling those products (primarily fuel oil, asphalt and other heavy refined products) to wholesale markets.

We also have the ability to use our terminal facilities to take advantage of contango market conditions, to gather and market crude oil, and to capitalize on regional opportunities which arise from time to time for both crude oil and petroleum products. When we purchase and store crude oil during periods of contango, we attempt to limit direct commodity price risk by simultaneously entering into a contract to sell the inventory in a future period, either with a counterparty or in the crude oil futures market.

Despite crude oil being considered a somewhat homogeneous commodity, many refiners are very particular about the quality of crude oil feedstock they process. Many U.S. refineries have distinct configurations and product slates that require crude oil with specific characteristics, such as gravity, sulfur content and metals content. The refineries evaluate the costs to obtain, transport and process their preferred feedstocks. That particularity provides us with opportunities to help the refineries in our areas of operation identify crude oil sources and transport crude oil meeting their requirements. The imbalances and inefficiencies relative to meeting the refiners’ requirements may also provide opportunities for us to utilize our purchasing and logistical skills and assets to meet their demands. The pricing in the majority of our crude oil purchase contracts contains a market price component and a deduction to cover the cost of transportation and to provide us with a margin. Contracts sometimes contain a grade differential which considers the chemical composition of the crude oil and its appeal to different customers. Typically, the pricing in a contract to sell crude oil will consist of the market price components and the grade differentials. The margin on individual transactions is then dependent on our ability to manage our transportation costs and to capitalize on grade differentials.

In our refined products marketing operations, we supply primarily fuel oil, asphalt and other heavy refined products to wholesale markets and some end-users such as paper mills and utilities. We also provide a service to refineries by purchasing “heavier” petroleum products that are the residual fuels from gasoline production, transporting them to one of our terminals and blending them to a quality that meets the requirements of our customers.

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
Gathering, marketing, and logistics revenue	$	152,804	$	115,929	$	467,514	$	311,066
Crude oil and CO2 pipeline tariffs and revenues	8,003		14,208		26,880		48,214
Distributions from unrestricted subsidiaries not included in income (1)	17,500		44,088		52,500		48,620
Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions	(128,804)		(104,197)		(415,171)		(258,474)
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses	(15,459)		(15,895)		(46,156)		(52,265)
Other	(4,899)		7,165		(13,055)		13,451
Segment Margin	$	29,145	$	61,298	$	72,512	$	110,612

Volumetric Data (average barrels per day unless otherwise noted):
Onshore crude oil pipelines:
Texas	64,027		64,635		60,561		70,444
Jay	7,694		9,731		8,133		8,276
Mississippi	5,088		5,523		5,171		5,605
Louisiana (2)	38,454		37,557		49,305		68,163

Onshore crude oil pipelines total	115,263		117,446		123,170		152,488

CO2 pipeline (average Mcf/day):
Free State (3)	—		90,649		—		106,530

Crude oil and petroleum products sales:
Total crude oil and petroleum products sales	20,878		29,284		24,292		25,772
Rail unload volumes	3,001		3,860		15,466		33,907

(1) The three and nine months ended September 30, 2021 include cash payments received from our previously owned NEJD pipeline of $17.5 million and $52.5 million not included in income, respectively. The three and nine months ended September 30, 2020 include total cash payments received from the NEJD pipeline of $46.5 million and $56.8 million, respectively, of which $44.1 million and $48.6 million, respectively, were not included in income.

(2) Total daily volume for the three and nine months ended September 30, 2021 includes 37,273 and 34,041 barrels per day of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines. Total daily volume for the three and nine months ended September 30, 2020 includes 33,874 and 35,676 barrels per day of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines.

(3) The assets owned by Genesis Free State Pipeline, LLC were sold on October 30, 2020.

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Onshore facilities and transportation Segment Margin for the 2021 Quarter decreased $32.2 million, or 52%. This decrease is primarily due to lower cash receipts of approximately $29 million received during the 2021 Quarter from Denbury associated with our previously owned NEJD pipeline. During the 2020 Quarter, we received a total of $46.5 million in cash payments associated with NEJD, including approximately $41 million associated with the exercise of a letter of credit we had issued to us as a result of our customer's default. During the 2021 Quarter, we received $17.5 million in cash payments with our previously owned NEJD pipeline as a result of our agreement reached during the fourth quarter of 2020 with Denbury. Additionally, we divested our Free State pipeline during the fourth quarter of 2020, which contributed positively to Segment Margin during the 2020 Quarter.

Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Onshore facilities and transportation Segment Margin for the first nine months of 2021 decreased $38.1 million, or 34%, from the first nine months of 2020. This decrease was primarily due to: (i) lower contracted minimum volume commitments with our main customer associated with our Baton Rouge corridor assets (including rail, terminal and pipeline volumes), as these commitments stepped down beginning in 2021, and the use of built up prepaid transportation credits during

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2021 by our main customer; and (ii) lower cash receipts of approximately $4.3 million associated with our previously owned NEJD pipeline during 2021; and (iii) the divestiture of our Free State pipeline during the fourth quarter of 2020, which contributed positively to Segment Margin for the first nine months of 2020.

Marine Transportation Segment

Within our marine transportation segment, we own a fleet of 91 barges (82 inland and 9 offshore) with a combined transportation capacity of 3.2 million barrels, 42 push/tow boats (33 inland and 9 offshore), and a 330,000 barrel ocean going tanker, the M/T American Phoenix. Operating results for our marine transportation segment were as follows:


	Three Months Ended September 30,						Nine Months Ended September 30,
	2021			2020			2021			2020
Revenues (in thousands):
Inland freight revenues	$	18,006		$	21,347		$	53,752		$	74,724
Offshore freight revenues	19,182			21,132			50,212			64,491
Other rebill revenues (1)	11,528			9,433			32,709			31,763
Total segment revenues	$	48,716		$	51,912		$	136,673		$	170,978

Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)	$	39,693		$	36,325		$	112,073		$	118,251

Segment Margin (in thousands)	$	9,023		$	15,587		$	24,600		$	52,727

Fleet Utilization: (2)
Inland Barge Utilization	79.9		%	74.0		%	77.7		%	85.0		%
Offshore Barge Utilization	93.5		%	95.7		%	95.2		%	97.3		%

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

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

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Marine transportation Segment Margin for the 2021 Quarter decreased $6.6 million, or 42%, from the 2020 Quarter. This decrease is primarily attributable to lower day rates in our inland business and on our M/T American Phoenix tanker during the 2021 Quarter relative to the 2020 Quarter. During the 2021 Quarter, we began to see improvement (especially as we exited the period) in our inland barge utilization, but we expect to see continued pressure on our utilization and rates as Midwest and Gulf Coast refineries have continued to run at lower utilization rates to better align with overall demand as a result of Covid-19 and the current operating environment, including the negative effects and temporary refinery shutdowns from Hurricane Ida in September. Additionally, we had a period of downtime for certain of our inland barge assets resulting from the storm. In our offshore barge operation, our previous five year contract associated with our M/T American Phoenix ended on September 30, 2020 and we have operated it under shorter term contracts and lower day rates since that period. Beginning in the second quarter of 2021, we re-contracted her with an investment grade refining company through the first quarter of 2022 at a more attractive day rate than the initial short term contracts we entered into between October 2020 and March 2021, albeit still lower than the day rate we received during the 2020 Quarter. We have continued to enter into short term contracts (less than a year) in both the inland and offshore markets because we believe the day rates currently being offered by the market have yet to fully recover.

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Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Marine transportation Segment Margin for the first nine months of 2021 decreased $28.1 million, or 53%, from the first nine months of 2020. This decrease is primarily attributable to lower utilization and day rates in our inland business during the 2021 Quarter and lower day rates in our offshore barge operation, including our M/T American Phoenix tanker. We expect to see continued pressure on our utilization and spot rates in our inland business as Midwest and Gulf Coast refineries have continued to run at lower utilization rates to better align with overall demand as a result of Covid-19 and the current operating environment. During 2020, our M/T American Phoenix received a higher day rate under its historical five year term contract that ended on September 30, 2020 compared to its shorter term contracts it operated under during 2021. The M/T American Phoenix is currently contracted through the first quarter of 2022 with an investment grade refining company. We have continued to enter into short term contracts (less than a year) in both the inland and offshore markets because we believe the day rates currently being offered by the market have yet to fully recover.

Other Costs, Interest, and Income Taxes

General and administrative expenses


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
General and administrative expenses not separately identified below:
Corporate	$	11,646	$	9,846	$	31,435	$	44,003
Segment	1,079		1,048		3,166		3,186
Long-term incentive compensation expense	743		143		2,705		(1,387)
Third party costs related to business development activities and growth projects	903		35		1,638		56
Total general and administrative expenses	$	14,371	$	11,072	$	38,944	$	45,858

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Total general and administrative expenses for the 2021 Quarter increased by $3.3 million. This increase is due to higher costs associated with our long term incentive compensation expense as a result of the assumptions used to value our outstanding awards, as well as an increase to corporate general and administrative costs and costs associated with business development activities and growth projects during the 2021 Quarter.

Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Total general and administrative expenses for the first nine months of 2021 decreased by $6.9 million primarily due to 2020 including a one-time charge of approximately $13 million related to certain severance and restructuring expenses. This increase was partially offset by higher long-term incentive compensation expense as a result of changes in assumptions used to value our outstanding awards between the two periods and an increase in costs associated with business development activities and growth projects during 2021.

Depreciation, depletion, and amortization expense


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
Depreciation and depletion expense	$	64,441	$	63,103	$	192,907	$	209,238
Amortization expense	2,707		4,630		8,068		12,972
Total depreciation, depletion and amortization expense	$	67,148	$	67,733	$	200,975	$	222,210

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Total depreciation, depletion, and amortization expense for the 2021 Quarter decreased by $0.6 million. This decrease is primarily due to lower amortization expense from our contract intangible associated with the M/T American Phoenix, which became fully amortized on September 30, 2020. This decrease was partially offset by an increase in depreciation expense as a result of assets being placed into service throughout 2021.

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Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Total depreciation, depletion, and amortization expense for the first nine months of 2021 decreased by $21.2 million due to lower depreciation expense associated with our rail logistics assets in 2021 as they were impaired during the second quarter of 2020. Additionally, our contract intangible associated with the M/T American Phoenix became fully amortized on September 30, 2020, which resulted in lower amortization expense during 2021.

Impairment Expense

During the three and nine months ended September 30, 2020, we recorded impairment expenses of $3.3 million and $280.8 million, respectively. During the nine months ended September 30, 2020, we recorded impairment expense of approximately $277.5 million associated with the rail logistics assets included within our onshore facilities and transportation segment. During the three and nine months ended September 30, 2020, we recorded impairment expense of $3.3 million associated with the full write-off of one of our non-core offshore gas platforms which did not have a future use with our operations. We had no impairment expense during 2021.

Interest expense, net


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
	(in thousands)				(in thousands)
Interest expense, senior secured credit facility (including commitment fees)	$	5,494	$	9,415	$	18,737	$	29,824
Interest expense, senior unsecured notes	53,079		39,842		153,273		122,402
Amortization of debt issuance costs and premium	2,276		2,454		7,246		7,045
Capitalized interest	(909)		(399)		(2,318)		(1,376)
Net interest expense	$	59,940	$	51,312	$	176,938	$	157,895

Three Months Ended September 30, 2021 Compared with Three Months Ended September 30, 2020

Net interest expense for the 2021 Quarter increased $8.6 million primarily due to increased interest expense associated with our senior unsecured notes. On December 17, 2020, we issued our $750 million 2027 Notes that accrue interest at 8.00% and we purchased and extinguished the remaining principal balance of our 6.00% 2023 Notes on January 19, 2021. On April 22, 2021, we issued an additional $250 million in aggregate principal amount of notes under the same terms as our 2027 Notes. The excess proceeds received from the issuance of our 2027 Notes were used to repay borrowings on our revolving credit facility.

The increase in interest expense on our senior unsecured notes was partially offset by lower interest expense on our senior secured credit facility. The decrease in interest expense on our senior secured credit facility was primarily due to a lower outstanding balance during the 2021 Quarter.

Nine Months Ended September 30, 2021 Compared with Nine Months Ended September 30, 2020

Net interest expense for the first nine months of 2021 increased by $19.0 million primarily due to increased interest expense associated with our senior unsecured notes. On January 16, 2020, we issued our $750 million 2028 Notes that accrue interest at 7.75% and we purchased and extinguished our $750 million 2022 notes that accrued interest at 6.75% during 2020. On December 17, 2020, we issued our $750 million 2027 Notes that accrue interest at 8.00% and we purchased and extinguished the remaining principal balance of our 6.00% 2023 Notes on January 19, 2021. On April 22, 2021, we issued an additional $250 million in aggregate principal amount of notes under the same terms as our 2027 Notes. The excess proceeds received from the issuance of our 2027 Notes were used to repay borrowings on our revolving credit facility.

Income tax expense

A portion of our operations are owned by wholly-owned corporate subsidiaries that are taxable as corporations. As a result, a substantial portion of the income tax expense we record relates to the operations of those corporations, and will vary from period to period as a percentage of our income before taxes based on the percentage of our income or loss that is derived from those corporations. The balance of the income tax expense we record relates to state taxes imposed on our operations that are treated as income taxes under generally accepted accounting principles and foreign income taxes.

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Liquidity and Capital Resources

General

On April 8, 2021, we entered into our new credit agreement to replace our existing agreement. Our new credit agreement provides for a $950 million senior secured credit facility, comprised of our Revolving Loan facility with a borrowing capacity of $650 million and our Term Loan facility with a borrowing capacity of $300 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 additional year on up to two occasions and subject to certain conditions. Under our new credit agreement, the permitted maximum consolidated leverage ratio is 5.75x through March 31, 2022, and then 5.50x thereafter. The permitted maximum consolidated senior secured leverage ratio is 2.50x, and the minimum interest coverage ratio is 2.50x for the full term of the agreement.

On December 17, 2020, we issued $750 million 2027 Notes that accrue interest at 8.00%. We used the net proceeds to repay a portion of our 6.00% 2023 Notes that were validly tendered and we redeemed the remaining principal balance of $80.9 million on our 6.00% 2023 Notes on January 19, 2021. The excess proceeds received from this offering were used to repay borrowings on our revolving credit facility. Furthermore, on April 22, 2021 we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The additional $250 million of notes have identical terms (other than with respect to issue price) and constitute part of the same series as our 2027 Notes. The $250 million of the 2027 Notes were issued at a premium of 103.75%, plus accrued interest from December 17, 2020. The net proceeds from this additional offering were used for general partnership purposes, including to pay down the outstanding borrowings on our Revolving Loan.

The successful completion of our new credit agreement (including its extended maturity and leverage flexibility) and the refinancing of our previously held 2023 Notes has resulted in no scheduled maturities of long-term debt until 2024, other than the minimal quarterly payments due under the associated term loan facility each quarter beginning at the end of 2021 (which will be funded by the available capacity under our revolving loan facility).

As of September 30, 2021, our balance sheet and liquidity position remained strong, which included $515.7 million of remaining borrowing capacity, subject to compliance with covenants, under our new $950 million senior secured credit facility. We anticipate that our future internally-generated funds and the funds available under our new credit agreement will allow us to meet our ordinary course capital needs. Our primary sources of liquidity have been cash flows from operations, borrowing availability under our prior credit facility and the proceeds from issuances of equity and senior unsecured notes.

Our primary cash requirements consist of:

•working capital, primarily inventories, payables and accrued liabilities;

•routine operating expenses;

•capital growth and maintenance projects;

•acquisitions of assets or businesses;

•payments related to servicing and reducing outstanding debt; and

•quarterly cash distributions to our preferred and common unitholders.

Capital Resources

Our ability to satisfy future capital needs will depend on our ability to raise substantial amounts of additional capital from time to time — including through equity and debt offerings (public and private), borrowings under our credit facility and other financing transactions—and to implement our growth strategy successfully. No assurance can be made that we will be able to raise necessary funds on satisfactory terms or implement our growth strategy successfully.

At September 30, 2021, our long-term debt totaled approximately $3,359.6 million, and consisted of $430.6 million outstanding under our senior secured credit facility, net (including $31.7 million borrowed under the inventory sublimit tranche) and $2,929.0 million of senior unsecured notes, net. Our senior unsecured notes, net balance is comprised of $338.8 million carrying amount due on June 2024, $530.1 million carrying amount due October 2025, $356.2 million carrying amount due May 2026, $993.0 million carrying value due January 2027, and $710.9 million carrying amount due February 2028. We remain focused on continuing to reduce our leverage.

On September 23, 2019, we announced the GOP. We entered into agreements with BXC for the purchase of up to approximately $350 million of Alkali Holdings preferred units. BXC is obligated to purchase a minimum of $250 million of Alkali Holdings preferred units. The proceeds received from BXC will fund up to 100% of the anticipated cost of the GOP. On April 14, 2020, we entered into an amendment to our agreements with BXC to, among other things, extend the construction timeline of the GOP by one year. The extended completion date of the project is anticipated in the second half of 2023. In consideration for the amendment, we issued 1,750 Alkali Holdings preferred units to BXC, which was accounted for as issuance costs. Additionally, the total commitment of BXC was increased to, subject to compliance with the covenants

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contained in the agreements with BXC, up to $351,750,000 in preferred units (or 351,750 preferred units) and the minimum purchase by BXC was increased to 251,750 Alkali Holdings preferred units. The Alkali Holdings preferred unitholders receive PIK distributions in lieu of cash distributions during the new anticipated construction period. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year. As of September 30, 2021, there are 246,394 Alkali Holdings preferred units issued and outstanding.

Shelf Registration Statement

We have the ability to issue additional equity and debt securities in the future to assist us in meeting our future liquidity requirements, particularly those related to opportunistically acquiring assets and businesses and constructing new facilities and refinancing outstanding debt.

We have a universal shelf registration statement (our "2021 Shelf") on file with the SEC which we filed on April 19, 2021 to replace our existing universal shelf registration statement that expired on April 20, 2021. Our 2021 Shelf allows us to issue an unlimited amount of equity and debt securities in connection with certain types of public offerings. However, the receptiveness of the capital markets to an offering of equity and/or debt securities cannot be assured and may be negatively impacted by, among other things, our long-term business prospects and other factors beyond our control, including market conditions. Our 2021 Shelf is set to expire in April 2024.

Cash Flows from Operations

We generally utilize the cash flows we generate from our operations to fund our distributions and working capital needs. Excess funds that are generated are used to repay borrowings under our credit facility and/or to fund a portion of our capital expenditures and asset retirement obligations (if any). Our operating cash flows can be impacted by changes in items of working capital, primarily variances in the carrying amount of inventory and the timing of payment of accounts payable and accrued liabilities related to capital expenditures.

We typically sell our purchased crude oil in the same month in which we acquire it, so we do not need to rely on borrowings under our credit facility to pay for such crude oil purchases, other than inventory. During such periods, our accounts receivable and accounts payable generally move in tandem, as we make payments and receive payments for the purchase and sale of crude oil.

In our petroleum products onshore facilities and transportation activities, we purchase products and typically either move those products to one of our storage facilities for further blending or sell those products within days of our purchase. The cash requirements for these activities can result in short term increases and decreases in our borrowings under our credit facility.

In our Alkali Business, we typically extract trona from our mining facilities, process it into soda ash and other alkali products, and deliver and sell the alkali products to our customers all within a relatively short time frame. If we do experience any differences in timing of extraction, processing and sales of our trona or alkali products, it could impact the cash requirements for these activities in the short term.

The storage of our inventory of crude oil and petroleum products can have a material impact on our cash flows from operating activities. In the month we pay for the stored crude oil or petroleum products, we borrow under our credit facility (or use cash on hand) to pay for the crude oil or petroleum products, utilizing a portion of our operating cash flows. Conversely, cash flow from operating activities increases during the period in which we collect the cash from the sale of the stored crude oil or petroleum products. Additionally, we may be required to deposit margin funds with the NYMEX when commodity prices increase as the value of the derivatives utilized to hedge the price risk in our inventory fluctuates. These deposits also impact our operating cash flows as we borrow under our credit facility or use cash on hand to fund the deposits.

See Note 14 in our Unaudited Condensed Consolidated Financial Statements for information regarding changes in components of operating assets and liabilities for the 2021 Quarter and 2020 Quarter.

Net cash flows provided by our operating activities for the nine months ended September 30, 2021 were $242.4 million compared to $295.6 million for the nine months ended September 30, 2020. This decrease is primarily attributable to changes in working capital and lower segment margin reported during 2021.

Capital Expenditures, Distributions and Certain Cash Requirements

We use cash primarily for our operating expenses, working capital needs, debt service, acquisition activities, organic growth projects, maintenance capital expenditures and distributions we pay to our preferred and common unitholders. We finance maintenance capital expenditures and smaller organic growth projects and distributions primarily with cash generated by our operations. We have historically funded material growth capital projects (including acquisitions and organic growth projects) with borrowings under our credit facility, equity issuances and/or issuances of senior unsecured notes. We currently plan to allocate a substantial portion of our excess cash flow to reduce the balance outstanding under our revolving credit facility and to opportunistically repurchase our outstanding senior unsecured notes.

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Capital Expenditures

A summary of our expenditures for fixed and intangible assets and equity investees for 2021 and 2020 are as follows:


	Nine Months Ended September 30,
	2021		2020
	(in thousands)
Capital expenditures for fixed and intangible assets:
Maintenance capital expenditures:
Offshore pipeline transportation assets	$	8,166	$	3,641
Sodium minerals and sulfur services assets	30,458		23,647
Marine transportation assets	29,757		22,998
Onshore facilities and transportation assets	4,382		2,988
Information technology systems	293		213
Total maintenance capital expenditures	73,056		53,487
Growth capital expenditures:
Offshore pipeline transportation assets	26,473		2,268
Sodium minerals and sulfur services assets	127,723		44,015
Marine transportation assets	—		—
Onshore facilities and transportation assets	133		444
Information technology systems	6,338		4,175
Total growth capital expenditures	160,667		50,902
Total capital expenditures for fixed and intangible assets	233,723		104,389




Capital expenditures related to equity investees	129		—
Total capital expenditures	$	233,852	$	104,389

Expenditures for capital assets to grow the partnership distribution will depend on our access to debt and equity capital. We will look for opportunities to acquire assets from other parties that meet our criteria for stable cash flows. We continue to pursue a long-term growth strategy that may require significant capital.

Growth Capital Expenditures

On September 23, 2019, we announced the GOP. The anticipated completion date of the project is the second half of 2023. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year.

We do not anticipate spending material growth capital expenditures on any other individual projects during the rest of 2021.

Maintenance Capital Expenditures

Maintenance capital expenditures incurred during 2021 primarily relate to expenditures in our Alkali Business, our marine transportation segment, and in our offshore transportation segment. Our Alkali Business, which is included in our sodium minerals and sulfur services segment, incurs expenditures to maintain its equipment and facilities due to the nature of its operations. Our marine transportation segment incurs expenditures as we frequently replace and upgrade certain equipment associated with our barge and vessel fleet during our planned and unplanned dry-docks. Additionally, we incur maintenance capital expenditures in our offshore transportation segment to replace certain pipeline and platform equipment, including the installation of a bypass to allow our CHOPS pipeline to resume operations in the 2021 Quarter. See further discussion under "Available Cash before Reserves" for how such maintenance capital utilization is reflected in our calculation of Available Cash before Reserves.

Distributions to Unitholders

On November 12, 2021, we will pay a distribution of $0.15 per common unit totaling $18.4 million with respect to the 2021 Quarter. Information on our recent distribution history is included in Note 10 to our Unaudited Condensed Consolidated Financial Statements. With respect to our Class A Convertible Preferred Units, we declared a quarterly cash distribution of $0.7374 per Class A Convertible Preferred Unit (or $2.9496 on an annualized basis) for each Class A Convertible Preferred Unit held of record. These distributions will be payable on November 12, 2021 to unitholders of record at the close of business on October 29, 2021.

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Guarantor Summarized Financial Information

Our $2.9 billion aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.'s current and future 100% Guarantor Subsidiaries. The assets owned by Genesis Free State Pipeline, LLC were sold on October 30, 2020 and the ownership of Genesis NEJD Pipeline, LLC's pipeline was transferred in October 2020. Genesis NEJD Pipeline, LLC is 100% owned by Genesis Energy, L.P., the parent company. The remaining non-guarantor subsidiaries are owned by Genesis Crude Oil, L.P., a Guarantor Subsidiary. The Guarantor Subsidiaries largely own the assets that we use to operate our business other than our Alkali Business. As a general rule, the assets and credit of our unrestricted subsidiaries are not available to satisfy the debts of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries, and the liabilities of our unrestricted subsidiaries do not constitute obligations of Genesis Energy, L.P., Genesis Energy Finance Corporation or the Guarantor Subsidiaries except, in the case of Alkali Holdings and Genesis Energy, L.P., to the extent agreed to in the Services Agreement. Genesis Energy Finance Corporation has no independent assets or operations. See Note 9 for additional information regarding our consolidated debt obligations.

The guarantees are senior unsecured obligations of each Guarantor Subsidiary and rank equally in right of payment with other existing and future senior indebtedness of such Guarantor Subsidiary, and senior in right of payment to all existing and future subordinated indebtedness of such Guarantor Subsidiary. The guarantee of our senior unsecured notes by each Guarantor Subsidiary is subject to certain automatic customary releases, including in connection with the sale, disposition or transfer of all of the capital stock, or of all or substantially all of the assets, of such Guarantor Subsidiary to one or more persons that are not us or a restricted subsidiary, the exercise of legal defeasance or covenant defeasance options, the satisfaction and discharge of the indentures governing our senior unsecured notes, the designation of such Guarantor Subsidiary as a non-guarantor restricted subsidiary or as an unrestricted subsidiary in accordance with the indentures governing our senior unsecured notes, the release of such Guarantor Subsidiary from its guarantee under our senior secured credit facility, or liquidation or dissolution of such Guarantor Subsidiary (collectively, the “Releases”). The obligations of each Guarantor Subsidiary under its note guarantee are limited as necessary to prevent such note guarantee from constituting a fraudulent conveyance under applicable law. We are not restricted from making investments in the Guarantor Subsidiaries and there are no significant restrictions on the ability of the Guarantor Subsidiaries to make distributions to Genesis Energy, L.P.

The rights of holders of our senior unsecured notes against the Guarantor Subsidiaries may be limited under the U.S. Bankruptcy Code or state fraudulent transfer or conveyance law.

The following is the summarized financial information for Genesis Energy, L.P. and the Guarantor Subsidiaries on a combined basis after elimination of intercompany transactions, which includes related receivable and payable balances, and the investment in and equity earnings from the Non-Guarantor Subsidiaries.


Balance Sheets	Genesis Energy, L.P. and Guarantor Subsidiaries
	September 30, 2021		December 31, 2020
ASSETS:
Current assets	$	264,609	$	313,328
Fixed assets, net	3,048,637		3,115,492
Non-current assets	822,525		861,230

LIABILITIES AND CAPITAL:(1)
Current liabilities	236,323		266,688
Non-current liabilities	3,713,459		3,710,044
Class A Convertible Preferred Units	790,115		790,115

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Statements of Operations	Genesis Energy, L.P. and Guarantor Subsidiaries
	Nine Months Ended September 30, 2021		Twelve Months Ended December 31. 2020
Revenues	$	1,027,705	$	1,156,428
Operating costs	963,260		1,421,674
Operating income (loss)	64,445		(265,246)
Loss before income taxes	(101,480)		(408,717)
Net loss(1)	(102,634)		(409,951)

Less: Accumulated distributions to Class A Convertible Preferred Units	(56,052)		(74,736)
Net loss available to common unitholders	(158,686)		(484,687)

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

Excluded from non-current assets in the table above are $46.3 million and $95.7 million of net intercompany receivables due to Genesis Energy, L.P. and the Guarantor Subsidiaries from the Non-Guarantor Subsidiaries as of September 30, 2021 and December 31, 2020, respectively.

Non-GAAP Financial Measure Reconciliations

For definitions and discussion of our Non-GAAP financial measures refer to the "Non-GAAP Financial Measures" as later discussed and defined.

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


	Three Months Ended September 30,
	2021		2020
	(in thousands)
Net loss attributable to Genesis Energy, L.P.	$	(20,899)	$	(29,717)
Income tax expense	423		145
Depreciation, depletion, amortization and accretion	69,665		70,203
Impairment expense	—		3,331
Plus (minus) Select Items, net	24,309		52,091
Maintenance capital utilized (1)	(13,500)		(10,600)
Cash tax expense	(195)		(250)
Distributions to preferred unitholders	(18,684)		(18,684)
Redeemable noncontrolling interest redemption value adjustments (2)	7,082		4,149

Available Cash before Reserves	$	48,201	$	70,668

(1)For a description of the term "maintenance capital utilized", please see the definition of the term "Available Cash before Reserves" discussed below. Maintenance capital expenditures in the 2021 Quarter and 2020 Quarter were $23.1 million and $19.9 million, respectively.

(2)Includes PIK distributions attributable to the period and accretion on the redemption feature.

We define Available Cash before Reserves (“Available Cash before Reserves”) as net income before interest, taxes, depreciation, depletion, and amortization (including impairment, write-offs, accretion and similar items) after eliminating other non-cash revenues, expenses, gains, losses and charges (including any loss on asset dispositions), plus or minus certain other select items that we view as not indicative of our core operating results (collectively, “Select Items”), as adjusted for certain items, the most significant of which in the relevant reporting periods have been the sum of maintenance capital utilized, net interest expense, cash tax expense, and cash distributions to our preferred unitholders. Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. The most significant Select Items in the relevant reporting periods are set forth below.

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		Three Months Ended September 30,
		2021		2020
		(in thousands)
I.	Applicable to all Non-GAAP Measures
	Differences in timing of cash receipts for certain contractual arrangements (1)	$	657	$	13,052
	Distribution from unrestricted subsidiaries not included in income (2)	17,500		44,088

	Certain non-cash items:
	Unrealized gains on derivative transactions excluding fair value hedges, net of changes in inventory value (3)	(1,708)		(9,772)

	Adjustment regarding equity investees (4)	7,142		2,318
	Other	(818)		2,060
	Sub-total Select Items, net	22,773		51,746
II.	Applicable only to Available Cash before Reserves
	Certain transaction costs (5)	903		55

	Other	633		290
	Total Select Items, net (6)	$	24,309	$	52,091

(1) 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. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

(2) The 2021 Quarter includes $17.5 million in cash receipts associated with principal repayments on our previously owned NEJD pipeline not included in income. The 2020 Quarter includes cash payments received from the NEJD pipeline of $44.1 million not included in income. Genesis NEJD Pipeline, LLC is defined as an unrestricted subsidiary under our credit facility.

(3) The 2021 Quarter includes a $1.7 million unrealized gain from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units and the 2020 Quarter includes a $6.7 million unrealized gain from the valuation of the embedded derivative.

(4) Represents the net effect of adding distributions from equity investees and deducting earnings of equity investees net to us.

(5) Represents transaction costs relating to certain merger, acquisition, divestiture, transition, and financing transactions incurred in advance of the associated transaction.

(6) Represents Select Items applicable to Adjusted EBITDA and Available Cash before Reserves.

Non-GAAP Financial Measures

General

To help evaluate our business, we use the non-generally accepted accounting principle (“non-GAAP”) financial measure of Available Cash before Reserves. We also present total Segment Margin as if it were a non-GAAP measure. Our non-GAAP measures may not be comparable to similarly titled measures of other companies because such measures may include or exclude other specified items. The schedules above provide reconciliations of Available Cash before Reserves to its most directly comparable financial measures calculated in accordance with generally accepted accounting principles in the United States of America (GAAP). A reconciliation of total Segment Margin to net loss is also included in our segment disclosure in Note 12 to our Unaudited Condensed Consolidated Financial Statements. Our non-GAAP financial measures should not be considered (i) as alternatives to GAAP measures of liquidity or financial performance or (ii) as being singularly important in any particular context; they should be considered in a broad context with other quantitative and qualitative information. Our Available Cash before Reserves and total Segment Margin measures are just two of the relevant data points considered from time to time.

When evaluating our performance and making decisions regarding our future direction and actions (including making discretionary payments, such as quarterly distributions) our board of directors and management team has access to a wide range of historical and forecasted qualitative and quantitative information, such as our financial statements; operational information; various non-GAAP measures; internal forecasts; credit metrics; analyst opinions; performance, liquidity and similar measures; income; cash flow; and expectations for us, and certain information regarding some of our peers. Additionally, our board of directors and management team analyze, and place different weight on, various factors from time to time. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts and other market participants. We attempt to provide adequate information to allow each individual investor and other external user to reach her/his own conclusions regarding our actions without providing so much information as to overwhelm or confuse such investor or other external user. Our non-GAAP financial measures should not be considered as an alternative to GAAP

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measures such as net income, operating income, cash flow from operating activities or any other GAAP measure of liquidity or financial performance.

Segment Margin

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. We define Segment Margin as revenues less product costs, operating expenses, and segment general and administrative expenses, after eliminating gain or loss on sale of assets, plus or minus applicable Select Items. Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results.

A reconciliation of total Segment Margin to net loss is included in our segment disclosure in Note 12 to our Unaudited Condensed Consolidated Financial Statements, as well as previously in this Item 2.

Available Cash before Reserves

Purposes, Uses and Definition

Available Cash before Reserves, often referred to by others as distributable cash flow, is a quantitative standard used throughout the investment community with respect to publicly traded partnerships and is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:

(1) the financial performance of our assets;

(2) our operating performance;

(3) the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;

(4) the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and

(5) our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.

Disclosure Format Relating to Maintenance Capital

We use a modified format relating to maintenance capital requirements because our maintenance capital expenditures vary materially in nature (discretionary vs. non-discretionary), timing and amount from time to time. We believe that, without such modified disclosure, such changes in our maintenance capital expenditures could be confusing and potentially misleading to users of our financial information, particularly in the context of the nature and purposes of our Available Cash before Reserves measure. Our modified disclosure format provides those users with information in the form of our maintenance capital utilized measure (which we deduct to arrive at Available Cash before Reserves). Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Requirements

Maintenance Capital Expenditures

Maintenance capital expenditures are capitalized costs that are necessary to maintain the service capability of our existing assets, including the replacement of any system component or equipment which is worn out or obsolete. Maintenance capital expenditures can be discretionary or non-discretionary, depending on the facts and circumstances.

Initially, substantially all of our maintenance capital expenditures were (a) related to our pipeline assets and similar infrastructure, (b) non-discretionary in nature and (c) immaterial in amount as compared to our Available Cash before Reserves measure. Those historical expenditures were non-discretionary (or mandatory) in nature because we had very little (if any) discretion as to whether or when we incurred them. We had to incur them in order to continue to operate the related pipelines in a safe and reliable manner and consistently with past practices. If we had not made those expenditures, we would not have been able to continue to operate all or portions of those pipelines, which would not have been economically feasible. An example of a non-discretionary (or mandatory) maintenance capital expenditure would be replacing a segment of an old pipeline because one can no longer operate that pipeline safely, legally and/or economically in the absence of such replacement.

As we exist today, a substantial amount of our maintenance capital expenditures from time to time will be (a) related to our assets other than pipelines, such as our marine vessels, trucks and similar assets, (b) discretionary in nature and (c) potentially material in amount as compared to our Available Cash before Reserves measure. Those expenditures will be discretionary (or non-mandatory) in nature because we will have significant discretion as to whether or when we incur them.

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We will not be forced to incur them in order to continue to operate the related assets in a safe and reliable manner. If we chose not to make those expenditures, we would be able to continue to operate those assets economically, although in lieu of maintenance capital expenditures, we would incur increased operating expenses, including maintenance expenses. An example of a discretionary (or non-mandatory) maintenance capital expenditure would be replacing an older marine vessel with a new marine vessel with substantially similar specifications, even though one could continue to economically operate the older vessel in spite of its increasing maintenance and other operating expenses.

In summary, as we continue to expand certain non-pipeline portions of our business, we are experiencing changes in the nature (discretionary vs. non-discretionary), timing and amount of our maintenance capital expenditures that merit a more detailed review and analysis than was required historically. Management’s recently increasing ability to determine if and when to incur certain maintenance capital expenditures is relevant to the manner in which we analyze aspects of our business relating to discretionary and non-discretionary expenditures. We believe it would be inappropriate to derive our Available Cash before Reserves measure by deducting discretionary maintenance capital expenditures, which we believe are similar in nature in this context to certain other discretionary expenditures, such as growth capital expenditures, distributions/dividends and equity buybacks. Unfortunately, not all maintenance capital expenditures are clearly discretionary or non-discretionary in nature. Therefore, we developed a measure, maintenance capital utilized, that we believe is more useful in the determination of Available Cash before Reserves. Our maintenance capital utilized measure, which is described in more detail below, constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Utilized

We believe our maintenance capital utilized measure is the most useful quarterly maintenance capital requirements measure to use to derive our Available Cash before Reserves measure. We define our maintenance capital utilized measure as that portion of the amount of previously incurred maintenance capital expenditures that we utilize during the relevant quarter, which would be equal to the sum of the maintenance capital expenditures we have incurred for each project/component in prior quarters allocated ratably over the useful lives of those projects/components.

Because we did not initially use our maintenance capital utilized measure, our future maintenance capital utilized calculations will reflect the utilization of solely those maintenance capital expenditures incurred since December 31, 2013.

Commitments and Off-Balance Sheet Arrangements

Contractual Obligations and Commercial Commitments

There have been no material changes to the commitments and obligations reflected in our Annual Report, other than the additional $250 million issuance of our 2027 Notes and our new credit agreement (including its extended maturity), which are discussed in further detail in Note 9.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements, special purpose entities, or financing partnerships, other than as disclosed under “Contractual Obligations and Commercial Commitments” in our Annual Report, nor do we have any debt or equity triggers based upon our unit or commodity prices.

Forward Looking Statements

The statements in this Quarterly Report on Form 10-Q that are not historical information may be “forward looking statements” as defined under federal law. All statements, other than historical facts, included in this document that address activities, events or developments that we expect or anticipate will or may occur in the future, including things such as plans for growth of the business, future capital expenditures, competitive strengths, goals, references to future goals or intentions, estimated or projected future financial performance, our expectations regarding the potential impact of the Covid-19 pandemic, the impact of our cost saving measures and the amount of such cost savings, and other such references are forward-looking statements, and historical performance is not necessarily indicative of future performance. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. They use words such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “could,” “plan,” “position,” “projection,” “strategy,” “should” or “will,” or the negative of those terms or other variations of them or by comparable terminology. In particular, statements, expressed or implied, concerning future actions, conditions or events or future operating results or the ability to generate sales, income or cash flow are forward-looking statements. Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future actions, conditions or events and future results of operations may differ materially from those expressed in these forward-looking statements. Many of the factors

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that will determine these results are beyond our ability or the ability of our affiliates to control or predict. Specific factors that could cause actual results to differ from those in the forward-looking statements include, among others:

•demand for, the supply of, our assumptions about, changes in forecast data for, and price trends related to crude oil, liquid petroleum, natural gas, NaHS, soda ash, and caustic soda, all of which may be affected by economic activity, capital expenditures by energy producers, weather, alternative energy sources, international events, pandemics (including Covid-19), the actions of OPEC and other oil exporting nations, conservation and technological advances;

•our ability to successfully execute our business and financial strategies;

•our ability to realize cost savings from our recent cost saving measures;

•the realized benefits of the preferred equity investment in Alkali Holdings by BXC or our ability to comply with the GOP agreements and maintain control over and ownership of the Alkali Business;

•throughput levels and rates;

•changes in, or challenges to, our tariff rates;

•our ability to successfully identify and close strategic acquisitions on acceptable terms (including obtaining third-party consents and waivers of preferential rights), develop or construct infrastructure assets, make cost saving changes in operations and integrate acquired assets or businesses into our existing operations;

•service interruptions in our pipeline transportation systems, processing operations, or mining facilities;

•shutdowns or cutbacks at refineries, petrochemical plants, utilities, individual plants, or other businesses for which we transport crude oil, petroleum, natural gas or other products or to whom we sell soda ash, petroleum, or other products;

•risks inherent in marine transportation and vessel operation, including accidents and discharge of pollutants;

•changes in laws and regulations to which we are subject, including tax withholding issues, regulations regarding qualifying income, accounting pronouncements, and safety, environmental and employment laws and regulations;

•the effects of production declines resulting from a suspension of drilling in the Gulf of Mexico or otherwise;

•the effects of future laws and regulations;

•planned capital expenditures and availability of capital resources to fund capital expenditures, and our ability to access the credit and capital markets to obtain financing on terms we deem acceptable;

•our inability to borrow or otherwise access funds needed for operations, expansions or capital expenditures as a result of our credit agreement and the indentures governing our notes, which contain various affirmative and negative covenants;

•loss of key personnel;

•cash from operations that we generate could decrease or fail to meet expectations, either of which could reduce our ability to pay quarterly cash distributions (common and preferred) at the current level or to increase quarterly cash distributions in the future;

•an increase in the competition that our operations encounter;

•cost and availability of insurance;

•hazards and operating risks that may not be covered fully by insurance;

•our financial and commodity hedging arrangements, which may reduce our earnings, profitability and cash flow;

•changes in global economic conditions, including capital and credit markets conditions, inflation and interest rates;

•the impact of natural disasters, pandemics (including Covid-19), epidemics, accidents or terrorism, and actions taken by governmental authorities and other third parties in response thereto, on our business financial condition and results of operations;

•reduction in demand for our services resulting in impairments of our assets;

•changes in the financial condition of customers or counterparties;

•adverse rulings, judgments, or settlements in litigation or other legal or tax matters;

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•the treatment of us as a corporation for federal income tax purposes or if we become subject to entity-level taxation for state tax purposes;

•the potential that our internal controls may not be adequate, weaknesses may be discovered or remediation of any identified weaknesses may not be successful and the impact these could have on our unit price; and

•a cyberattack involving our information systems and related infrastructure, or that of our business associates.

You should not put undue reliance on any forward-looking statements. When considering forward-looking statements, please review the risk factors described under “Risk Factors” discussed in Item 1A of our Annual Report . These risks may also be specifically described in our Quarterly Reports on Form 10-Q, Current Reports on Form 8-K (or any amendments to those reports) and other documents that we may file from time to time with the SEC. New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time to time, and it is not possible for us to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those contained in any forward-looking statement. Except as required by applicable securities laws, we do not intend to update these forward-looking statements and information.

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Item 3. Quantitative and Qualitative Disclosures about Market Risk

The following should be read in conjunction with Quantitative and Qualitative Disclosures About Market Risk included under Item 7A in our Annual Report. There have been no material changes that would affect the quantitative and qualitative disclosures provided therein. Also, see Note 15 to our Unaudited Condensed Consolidated Financial Statements for additional discussion related to derivative instruments and hedging activities.

Item 4. Controls and Procedures

We maintain disclosure controls and procedures and internal controls designed to ensure that information required to be disclosed in our filings under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in the SEC's rules and forms. Our chief executive officer and chief financial officer, with the participation of our management, have evaluated our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10-Q and have determined that such disclosure controls and procedures are effective in ensuring that material information required to be disclosed in this Quarterly Report on Form 10-Q is accumulated and communicated to them and our management to allow timely decisions regarding required disclosures.

There were no changes during the 2021 Quarter that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Information with respect to this item has been incorporated by reference from our Annual Report on Form 10-K for the year ended December 31, 2020 (the "Annual Report"). There have been no material developments in legal proceedings since the filing of such Form 10-K.

Item 1A. Risk Factors

There has been no material change in our risk factors as previously disclosed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

For additional information about our risk factors, see Item 1A of our Annual Report, as well as any other risk factors contained in other filings with the SEC, including Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and Form 8-K/A and other documents that we may file from time to time with the SEC.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

There were no sales of unregistered equity securities during the 2021 Quarter.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Information regarding mine safety and other regulatory action at our mines in Green River and Granger, Wyoming is included in Exhibit 95 to this Form 10-Q.

Item 5. Other Information

None.

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Item 6. Exhibits.

(a) Exhibits


	3.1	Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.1 to Amendment No. 2 of the Registration Statement on Form S-1, File No. 333-11545).
	3.2	Amendment to the Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.2 to the Company's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2011, File No. 001-12295).
	3.3	Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 5.1 to the Company's Current Report on Form 8-K dated January 3, 2011, File No. 001-12295).
	3.4	First Amendment to Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P., dated September 1, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated September 7, 2017, File No. 001-12295).
	3.5	Second Amendment to Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P., dated December 31, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K dated January 4, 2018, File No. 001-12295).
	3.6	Certificate of Conversion of Genesis Energy, Inc. a Delaware corporation, into Genesis Energy, LLC, a Delaware limited liability company (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K dated January 7, 2009, File No. 001-12295).
	3.7	Certificate of Formation of Genesis Energy, LLC (formerly Genesis Energy, Inc.) (incorporated by reference to Exhibit 3.2 to the Company's Current Report on Form 8-K dated January 7, 2009, File No. 001-12295).
	3.8	Second Amended and Restated Limited Liability Company Agreement of Genesis Energy, LLC dated December 28, 2010 (incorporated by reference to Exhibit 5.2 to the Company's Current Report on Form 8-K dated January 3, 2011, File No. 001-12295).
	3.9	Certificate of Incorporation of Genesis Energy Finance Corporation, dated as of November 26, 2006 (incorporated by reference to Exhibit 3.7 to Registration Statement on Form S-4 filed on September 26, 2011, File No. 333-177012).
	3.10	Bylaws of Genesis Energy Finance Corporation (incorporated by reference to Exhibit 3.8 to Registration Statement on Form S-4 filed on September 26, 2011, File No. 333-177012).
	4.1	Form of Unit Certificate of Genesis Energy, L.P. (incorporated by reference to Exhibit 4.1 to the Company's Annual Report on Form 10-K for the year ended December 31, 2007, File No. 001-12295).
	22.1	List of Issuers and Guarantor Subsidiaries (incorporated by reference to Exhibit 22.1 to the Company's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2021, File No. 001-12295)
*	31.1	Certification by Chief Executive Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
*	31.2	Certification by Chief Financial Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
*	32	Certification by Chief Executive Officer and Chief Financial Officer Pursuant to Rule 13a-14(b) of the Securities Exchange Act of 1934.
*	95	Mine Safety Disclosures.
	101.INS	XBRL Instance Document- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
	101.SCH	XBRL Schema Document.
	101.CAL	XBRL Calculation Linkbase Document.
	101.LAB	XBRL Label Linkbase Document.
	101.PRE	XBRL Presentation Linkbase Document.
	101.DEF	XBRL Definition Linkbase Document.
	104	Cover Page Interactive Data File (formatted as Inline XBRL).


*			Filed herewith

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


						GENESIS ENERGY, L.P. (A Delaware Limited Partnership)

			By:			GENESIS ENERGY, LLC, as General Partner


Date:	November 4, 2021	By:	/s/ ROBERT V. DEERE
			Robert V. Deere
			Chief Financial Officer
			(Duly Authorized Officer)