Docoh
Loading...

GEL Genesis Energy

Filed: 4 Aug 21, 11:22am
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 June 30, 2021
OR
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)

Delaware76-0513049
(State or other jurisdiction of
incorporation or organization)
(I.R.S. Employer
Identification No.)
919 Milam, Suite 2100,
Houston,TX77002
(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 ClassTrading Symbol(s)Name of Each Exchange on Which Registered
Common unitsGELNYSE
 
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  ¨







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 filerxAccelerated 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 August 4, 2021.


GENESIS ENERGY, L.P.
TABLE OF CONTENTS
 
2

PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
GENESIS ENERGY, L.P.
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except units)  
June 30, 2021December 31, 2020
ASSETS
CURRENT ASSETS:
Cash and cash equivalents$24,205 $21,282 
Restricted cash22,083 5,736 
Accounts receivable - trade, net433,310 392,465 
Inventories78,327 99,877 
Other61,796 60,809 
Total current assets619,721 580,169 
FIXED ASSETS, at cost5,312,157 5,173,475 
Less: Accumulated depreciation(1,437,510)(1,322,141)
Net fixed assets3,874,647 3,851,334 
MINERAL LEASEHOLDS, net of accumulated depletion550,959 552,575 
EQUITY INVESTEES302,940 319,068 
INTANGIBLE ASSETS, net of amortization127,947 128,742 
GOODWILL301,959 301,959 
RIGHT OF USE ASSETS, net144,013 153,925 
OTHER ASSETS, net of amortization41,301 45,847 
TOTAL ASSETS$5,963,487 $5,933,619 
LIABILITIES AND CAPITAL
CURRENT LIABILITIES:
Accounts payable - trade$301,676 $198,433 
Accrued liabilities218,327 184,978 
Total current liabilities520,003 383,411 
SENIOR SECURED CREDIT FACILITY, net415,653 643,700 
SENIOR UNSECURED NOTES, net2,927,489 2,750,016 
DEFERRED TAX LIABILITIES13,719 13,317 
OTHER LONG-TERM LIABILITIES422,299 393,018 
Total liabilities4,299,163 4,183,462 
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 25,336,778 issued and outstanding at June 30, 2021 and December 31, 2020790,115 790,115 
Redeemable noncontrolling interests, 201,705 and 141,249 preferred units issued and outstanding at June 30, 2021 and December 31, 2020, respectively204,647 141,194 
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 units issued and outstanding at June 30, 2021 and December 31, 2020679,278 829,326 
Accumulated other comprehensive loss(9,122)(9,365)
Noncontrolling interests(594)(1,113)
Total partners' capital669,562 818,848 
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL$5,963,487 $5,933,619 
The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.
3


GENESIS ENERGY, L.P.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands)
 
 Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
REVENUES:
Offshore pipeline transportation$73,221 $64,964 $137,605 $143,393 
Sodium minerals and sulfur services237,087 192,624 464,374 436,014 
Marine transportation47,626 56,720 87,957 119,066 
Onshore facilities and transportation145,921 74,159 335,138 229,917 
Total revenues503,855 388,467 1,025,074 928,390 
COSTS AND EXPENSES:
Onshore facilities and transportation product costs124,684 43,447 285,435 155,399 
Onshore facilities and transportation operating costs15,833 18,238 32,095 36,486 
Marine transportation operating costs39,118 38,561 72,204 81,498 
Sodium minerals and sulfur services operating costs196,971 167,010 381,402 372,243 
Offshore pipeline transportation operating costs21,264 16,403 41,980 35,064 
General and administrative12,907 25,413 24,573 34,786 
Depreciation, depletion and amortization67,541 80,120 133,827 154,477 
Impairment expense277,495 277,495 
Total costs and expenses478,318 666,687 971,516 1,147,448 
OPERATING INCOME (LOSS)25,537 (278,220)53,558 (219,058)
Equity in earnings of equity investees14,222 12,618 34,882 26,777 
Interest expense(59,169)(51,618)(116,998)(106,583)
Other income (expense)(15,845)(4,550)(35,910)5,708 
Loss from operations before income taxes(35,255)(321,770)(64,468)(293,156)
Income tax expense(525)(795)(747)(430)
NET LOSS(35,780)(322,565)(65,215)(293,586)
Net loss (income) attributable to noncontrolling interests(136)10 (134)26 
Net income attributable to redeemable noncontrolling interests(5,766)(4,159)(10,557)(8,245)
NET LOSS ATTRIBUTABLE TO GENESIS ENERGY, L.P.$(41,682)$(326,714)$(75,906)$(301,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units(18,684)(18,684)(37,368)(37,368)
NET LOSS AVAILABLE TO COMMON UNITHOLDERS$(60,366)$(345,398)$(113,274)$(339,173)
NET LOSS PER COMMON UNIT (Note 11):
Basic and Diluted$(0.49)$(2.82)$(0.92)$(2.77)
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted122,579 122,579 122,579 122,579 
The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

4

GENESIS ENERGY, L.P.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(In thousands)
Three Months Ended
June 30,
Six Months Ended
June 30,
2021202020212020
Net loss$(35,780)$(322,565)$(65,215)$(293,586)
Other comprehensive income:
Amortization of prior service cost121 243 243 243 
Total Comprehensive loss(35,659)(322,322)(64,972)(293,343)
Comprehensive loss (income) attributable to noncontrolling interests(136)10 (134)26 
Comprehensive income attributable to redeemable noncontrolling interests(5,766)(4,159)(10,557)(8,245)
Comprehensive loss attributable to Genesis Energy, L.P.$(41,561)$(326,471)$(75,663)$(301,562)
The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

5


GENESIS ENERGY, L.P.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL
(In thousands)
Number of Common UnitsPartners’ CapitalNoncontrolling InterestAccumulated Other Comprehensive LossTotal
Partners' capital, March 31, 2021122,579 $758,031 $(879)$(9,243)$747,909 
Net income (loss)— (41,682)136 — (41,546)
Cash distributions to partners— (18,387)— — (18,387)
Cash contributions from noncontrolling interests— — 149 — 149 
Other comprehensive income— — — 121 121 
Distributions to Class A Convertible Preferred unitholders— (18,684)— — (18,684)
Partners' capital, June 30, 2021122,579 $679,278 $(594)$(9,122)$669,562 
Number of Common UnitsPartners’ CapitalNoncontrolling InterestAccumulated Other Comprehensive LossTotal
Partners' capital, March 31, 2020122,579 $1,382,126 $(2,357)$(8,431)$1,371,338 
Net loss— (326,714)(10)— (326,724)
Cash distributions to partners— (18,386)— — (18,386)
Cash contributions from noncontrolling interests— — 467 — 467 
Other comprehensive income— — — 243 243 
Distributions to Class A Convertible Preferred unitholders— (18,684)— — (18,684)
Partners' capital, June 30, 2020122,579 $1,018,342 $(1,900)$(8,188)$1,008,254 
 Number of
Common Units
Partners’ CapitalNoncontrolling InterestAccumulated Other Comprehensive LossTotal
Partners’ capital, December 31, 2020122,579 $829,326 $(1,113)$(9,365)$818,848 
Net income (loss)— (75,906)134 — (75,772)
Cash distributions to partners— (36,774)— — (36,774)
Cash contributions from noncontrolling interests— — 385 — 385 
Other comprehensive income— — — 243 243 
Distributions to Class A Convertible Preferred unitholders— (37,368)— — (37,368)
Partners' capital, June 30, 2021122,579 $679,278 $(594)$(9,122)$669,562 
Number of
Common Units
Partners’ CapitalNoncontrolling InterestAccumulated Other Comprehensive LossTotal
Partners’ capital, December 31, 2019122,579 $1,443,320 $(3,718)$(8,431)$1,431,171 
Net loss— (301,805)(26)— (301,831)
Cash distributions to partners— (85,805)— — (85,805)
Cash contributions from noncontrolling interests— — 1,844 — 1,844 
Other comprehensive income— — — 243 243 
Distributions to Class A Convertible Preferred unitholders— (37,368)— — (37,368)
Partners' capital, June 30, 2020122,579 $1,018,342 $(1,900)$(8,188)$1,008,254 
    
The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.
6

GENESIS ENERGY, L.P.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
 
 Six Months Ended
June 30,
 20212020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss$(65,215)$(293,586)
Adjustments to reconcile net loss to net cash provided by operating activities -
Depreciation, depletion and amortization133,827 154,477 
Impairment expense277,495 
Amortization and write-off of debt issuance costs, premium and discount6,965 14,971 
Amortization of non-cash costs on previously owned direct financing leases(5,802)
Payments received under previously owned direct financing leases (Note 4)
35,000 10,334 
Equity in earnings of investments in equity investees(34,882)(26,777)
Cash distributions of earnings of equity investees34,325 25,923 
Non-cash effect of long-term incentive compensation plans2,884 (3,647)
Deferred and other tax liabilities402 130 
Unrealized losses (gains) on derivative transactions32,377 (9,811)
Cancellation of debt income(19,725)
Other, net11,229 8,662 
Net changes in components of operating assets and liabilities (Note 14)
31,272 19,518 
Net cash provided by operating activities188,184 152,162 
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets(111,412)(69,438)
Cash distributions received from equity investees - return of investment17,015 13,036 
Proceeds from asset sales32 304 
Net cash used in investing activities(94,365)(56,098)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility366,600 684,500 
Repayments on senior secured credit facility(592,100)(590,800)
Proceeds from issuance of senior unsecured notes (Note 9)
259,375 750,000 
Net proceeds from issuance of preferred units (Note 10)
53,018 
Repayment of senior unsecured notes (Note 9)
(80,859)(820,713)
Debt issuance costs(11,365)(13,297)
Contributions from noncontrolling interests385 1,844 
Distributions to common unitholders(36,774)(85,805)
Distributions to preferred unitholders(37,368)(37,368)
Other, net4,539 4,671 
Net cash used in financing activities(74,549)(106,968)
Net increase (decrease) in cash, restricted cash, and cash equivalents19,270 (10,904)
Cash, restricted cash and cash equivalents at beginning of period27,018 56,405 
Cash, restricted cash and cash equivalents at end of period$46,288 $45,501 
The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.
7

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 4 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.
8

Beginning in March 2020, Covid-19 caused commodity prices to decline due to, among other things, reduced industrial activity and travel demand. Additionally, actions taken by OPEC and other oil exporting nations
in that timeframe caused additional significant declines and 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 have early adopted the amendment and included the required summarized financial information in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.
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 June 30, 2021 and 2020, respectively:
Three Months Ended
June 30, 2021
Offshore Pipeline TransportationSodium Minerals & Sulfur ServicesMarine TransportationOnshore Facilities and TransportationConsolidated
Fee-based revenues$73,221 $$47,626 $18,176 $139,023 
Product Sales212,434 127,745 340,179 
Refinery Services24,653 24,653 
$73,221 $237,087 $47,626 $145,921 $503,855 
Three Months Ended
June 30, 2020
Offshore Pipeline TransportationSodium Minerals & Sulfur ServicesMarine TransportationOnshore Facilities and TransportationConsolidated
Fee-based revenues$64,964 $$56,720 $21,845 $143,529 
Product Sales172,410 52,314 224,724 
Refinery Services20,214 20,214 
$64,964 $192,624 $56,720 $74,159 $388,467 
9

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 six months ended June 30, 2021 and 2020, respectively:
Six Months Ended
June 30, 2021
Offshore Pipeline TransportationSodium Minerals & Sulfur ServicesMarine TransportationOnshore Facilities and TransportationConsolidated
Fee-based revenues$137,605 $$87,957 $42,570 $268,132 
Product Sales417,212 292,568 709,780 
Refinery Services47,162 47,162 
$137,605 $464,374 $87,957 $335,138 $1,025,074 
Six Months Ended
June 30, 2020
Offshore Pipeline TransportationSodium Minerals & Sulfur ServicesMarine TransportationOnshore Facilities & TransportationConsolidated
Fee-based revenues$143,393 $$119,066 $62,835 $325,294 
Product Sales387,776 167,082 554,858 
Refinery Services48,238 48,238 
$143,393 $436,014 $119,066 $229,917 $928,390 

    The Company recognizes revenue upon the satisfaction of its performance obligations under its contracts. The timing of revenue recognition varies for our different revenue streams. In general, the timing includes recognition of revenue over time as services are being performed as well as recognition of revenue at a point in time, for delivery of products.

Contract Assets and Liabilities
    The table below depicts our contract asset and liability balances at December 31, 2020 and June 30, 2021:
Contract AssetsContract Liabilities
Current Assets- OtherOther AssetsAccrued LiabilitiesOther Long-Term Liabilities
Balance at December 31, 2020$36,500 $12,065 $2,988 $19,834 
Balance at June 30, 202130,813 2,669 18,576 


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 June 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.
10

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 TransportationOnshore Facilities and Transportation
Remainder of 2021$31,048 $9,604 
202275,623 4,698 
202363,982 
202456,326 
202560,311 
Thereafter97,761 
Total$385,051 $14,302 



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 six months ended June 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 six months ended June 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
June 30,
Six Months Ended
 June 30,
2021202020212020
M/T American Phoenix$3,819 $6,734 $7,239 $13,377 
Free State Pipeline (1)
1,499 3,422 
(1) We sold the Free State pipeline to a subsidiary of Denbury, Inc. ("Denbury") on October 30, 2020.
11

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 4 equal installments. During the six months ended June 30, 2021, we collected $35.0 million and we have an outstanding receivable (included within "Accounts receivable- trade, net" on the Unaudited Condensed Consolidated Balance Sheet) of $35.0 million as of June 30, 2021 from Denbury for the remaining payments due in 2021 per the agreement. Additionally as part of this transaction, we transferred the ownership of all of our CO2 assets to Denbury, including the Free State pipeline system as noted previously.

5. Inventories
The major components of inventories were as follows:
June 30,
2021
December 31, 2020
Petroleum products$1,308 $5,840 
Crude oil23,597 37,661 
Caustic soda4,459 5,167 
NaHS10,701 9,101 
Raw materials - Alkali operations7,230 7,120 
Work-in-process - Alkali operations4,455 9,355 
Finished goods, net - Alkali operations13,279 13,002 
Materials and supplies, net - Alkali operations13,298 12,631 
Total$78,327 $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 $0.5 million and $5.0 million as of June 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.
12

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:
 
June 30, 2021December 31, 2020
Crude oil pipelines and natural gas pipelines and related assets$2,821,996 $2,811,030 
Alkali facilities, machinery, and equipment641,619 622,598 
Onshore facilities, machinery, and equipment268,689 267,810 
Transportation equipment21,348 19,470 
Marine vessels1,011,171 998,553 
Land, buildings and improvements221,146 219,382 
Office equipment, furniture and fixtures22,185 22,001 
Construction in progress260,742 170,740 
Other43,261 41,891 
Fixed assets, at cost5,312,157 5,173,475 
Less: Accumulated depreciation(1,437,510)(1,322,141)
Net fixed assets$3,874,647 $3,851,334 

Mineral Leaseholds
Our Mineral Leaseholds, relating to our Alkali Business, consist of the following:
June 30,
2021
December 31, 2020
Mineral leaseholds$566,019 $566,019 
Less: Accumulated depletion(15,060)(13,444)
Mineral leaseholds, net of accumulated depletion$550,959 $552,575 

Our depreciation and depletion expense for the periods presented was as follows:
Three Months Ended
June 30,
Six Months Ended
June 30,
2021202020212020
Depreciation expense$64,148 $75,089 $126,850 $144,331 
Depletion expense704 841 1,616 1,804 

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.
Asset Retirement Obligations
    We record asset retirement obligations ("AROs") in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations.
The following table presents information regarding our AROs since December 31, 2020:
13

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
ARO liability balance, December 31, 2020$176,852 
Accretion expense5,177 
Changes in estimate97 
Settlements(2,824)
ARO liability balance, June 30, 2021$179,302 
    Of the ARO balances disclosed above, $12.3 million and $14.7 million is included as current in "Accrued liabilities" on our Unaudited Condensed Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020, respectively. The remainder of the ARO liability as of June 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 of2021$4,975 
2022$9,384 
2023$9,128 
2024$9,783 
2025$10,487 
    Certain of our unconsolidated affiliates have AROs recorded at June 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 June 30, 2021 and December 31, 2020, the unamortized excess cost amounts totaled $327.6 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
June 30,
Six Months Ended
June 30,
 2021202020212020
Genesis’ share of operating earnings$18,094 $16,490 $42,627 $34,522 
Amortization of excess purchase price(3,872)(3,872)(7,745)(7,745)
Net equity in earnings$14,222 $12,618 $34,882 $26,777 
Distributions received (1)
$21,914 $18,394 $51,430 $38,959 
(1) Includes distributions attributable to the period and received during or promptly following such period.
14

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):
June 30,
2021
December 31, 2020
BALANCE SHEET DATA:
Assets
Current assets$17,546 $30,465 
Fixed assets, net167,764 171,732 
Other assets5,447 4,673 
Total assets$190,757 $206,870 
Liabilities and equity
Current liabilities$13,649 $9,958 
Other liabilities229,836 237,595 
Equity (Deficit)(52,728)(40,683)
Total liabilities and equity$190,757 $206,870 
 Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
INCOME STATEMENT DATA:
Revenues$33,757 $30,419 $76,170 $63,311 
Operating income$24,636 $21,922 $56,797 $45,528 
Net income$23,610 $20,636 $54,755 $42,219 


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:
 
 June 30, 2021December 31, 2020
 Gross
Carrying
Amount
Accumulated
Amortization
Carrying
Value
Gross
Carrying
Amount
Accumulated
Amortization
Carrying
Value
Marine contract intangibles$800 $589 $211 $800 $571 $229 
Offshore pipeline contract intangibles158,101 49,233 108,868 158,101 45,073 113,028 
Other33,629 14,761 18,868 29,244 13,759 15,485 
Total$192,530 $64,583 $127,947 $188,145 $59,403 $128,742 

Our amortization of intangible assets for the periods presented was as follows:
Three Months Ended
June 30,
Six Months Ended
June 30,
2021202020212020
Amortization of intangible assets$2,580 $4,146 $5,180 $8,262 
15

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 of2021$5,673 
2022$11,244 
2023$10,976 
2024$10,661 
2025$10,494 
9. Debt
Our obligations under debt arrangements consisted of the following:
 June 30, 2021December 31, 2020
 PrincipalUnamortized Premium and Debt Issuance CostsNet ValuePrincipalUnamortized Debt Issuance CostsNet Value
Senior secured credit facility-Revolving Loan (1)
$118,200 $$118,200 $643,700 $$643,700 
Senior secured credit facility-Term Loan (2)
300,000 2,547 297,453 
6.000% senior unsecured notes due 202380,859 504 80,355 
5.625% senior unsecured notes due 2024341,135 2,534 338,601 341,135 2,963 338,172 
6.500% senior unsecured notes due 2025534,834 5,046 529,788 534,834 5,639 529,195 
6.250% senior unsecured notes due 2026359,799 3,799 356,000 359,799 4,189 355,610 
8.000% senior unsecured notes due 20271,000,000 7,401 992,599 750,000 13,022 736,978 
7.750% senior unsecured notes due 2028720,975 10,474 710,501 720,975 11,269 709,706 
Total long-term debt$3,374,943 $31,801 $3,343,142 $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 Long Term Assets on the Unaudited Condensed Consolidated Balance Sheets), were $5.5 million and $5.8 million as of June 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 $2.5 million as of June 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 2 occasions and subject to certain conditions. At June 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 June 30, 2021, the applicable margins on our borrowings were 2.75% for alternate base rate borrowings and 3.75% 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
16

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 June 30, 2021, our letter of credit rate was 3.75%.
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 June 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 June 30, 2021, we had $118.2 million outstanding under our Revolving Loan, with $19.6 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 June 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 June 30, 2021 was $530.5 million, subject to compliance with covenants.
At June 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:
Year
Principal Due (1)
2021$15,000 
202260,000 
2023100,000 
2024125,000 
(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 5.85x through June 30, 2021, 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 June 30, 2021, we were in compliance with the financial covenants contained in our new credit agreement and indentures for our senior unsecured notes indentures 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 six months ended June 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
17

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
debt issuance costs, which is recorded in "Other income (expense)" in our Unaudited Condensed Consolidated Statements of Operations for the six months ended June 30, 2021.
On April 22, 2021, we completed our offering of an additional $250 million in aggregate principal amount of our 2027 Notes. The notes constitute an additional issuance of our existing 2027 Notes that we issued on December 17, 2020 in an aggregate principal amount of $750 million. The additional $250 million of notes have identical terms as (other than with respect to the issue price) and constitute part of the same series of the 2027 Notes. The $250 million of the 2027 Notes were issued at a premium of 103.75% plus accrued interest from December 17, 2020. We used the net proceeds from the offering for general partnership purposes, including repaying a portion of the revolving borrowings outstanding under our new credit agreement.
During 2020, we repurchased certain of our senior unsecured notes on the open market and recorded cancellation of
debt income of $18.5 million and $19.7 million for the three and six months ended June 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 June 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 ForDate PaidPer 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(1)$0.15 $18,387 
(1) This distribution was declared on July 7, 2021 and will be paid to unitholders of record as of July 30, 2021.

18

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Class A Convertible Preferred Units
At June 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 $37.4 million for the three and six months ended June 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 ForDate PaidPer 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(1)$0.7374 $18,684 
(1) This distribution was declared on July 7, 2021 and will be paid to unitholders of record as of July 30, 2021.

19

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 GSO Capital Partners LP (collectively "GSO") purchased $55,000,000 (or 55,000 Alkali Holdings preferred units) and committed to purchase up to $350,000,000 of preferred units in Alkali Holdings, the entity that holds our trona and trona-based exploring, mining, processing, producing, marketing and selling business, including its Granger facility near Green River, Wyoming. Alkali Holdings will use the net proceeds from the Alkali Holdings preferred units to fund up to 100% of the anticipated cost of expansion of the Granger facility (the "Granger Optimization Project" or "GOP"). On April 14, 2020, we entered into an amendment to our agreements with GSO 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 GSO, which was accounted for as issuance costs. As part of the amendment, the commitment period was increased to four years, and the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. As of June 30, 2021, there are 201,705 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 June 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 June 30, 2021 includes $5.8 million of adjustments, of which $4.9 million was allocated to the paid-in-kind ("PIK") distributions on the outstanding Alkali Holdings preferred units and $0.9 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the six months ended June 30, 2021 includes $10.6 million of adjustments, of which $9.0 million was allocated to the PIK distributions on the outstanding Alkali Holdings preferred units and $1.6 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the three months ended June 30, 2020 includes $4.2 million of adjustments, of which $3.4 million was allocated to the PIK distributions and $0.8 million was attributable to redemption accretion value adjustments. Net Loss Attributable to Genesis Energy, L.P. for the six months ended June 30, 2020 includes $8.2 million of adjustments, of which $6.7 million was allocated to the PIK distributions and $1.5 million was attributable to redemption accretion value adjustments. We elected to pay distributions for the period ended June 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 June 30, 2021, the redemption amount would be equal to $248.9 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.
20

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 June 30, 2021:
Balance as of December 31, 2020$141,194 
Issuance of preferred units, net of issuance costs (1)
59,247 
PIK distribution8,955 
Redemption accretion1,602 
Tax distributions (1)
(6,351)
Balance as of June 30, 2021$204,647 
(1) During the period ended June 30, 2021, we issued 6,356 Alkali Holdings preferred units to GSO to satisfy the company's obligation to pay tax distributions. Additionally, we issued 54,100 Alkali Holdings preferred units to GSO during the six months ended June 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 six months ended June 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
June 30,
Six Months Ended
June 30,
2021202020212020
Net Loss Attributable to Genesis Energy L.P.$(41,682)$(326,714)$(75,906)$(301,805)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units(18,684)(18,684)(37,368)(37,368)
Net Loss Available to Common Unitholders$(60,366)$(345,398)$(113,274)$(339,173)
Weighted Average Outstanding Units122,579 122,579 122,579 122,579 
Basic and Diluted Net Loss per Common Unit$(0.49)$(2.82)$(0.92)$(2.77)


21

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
12. Business Segment Information
    We currently manage our businesses through 4 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. 
22

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Segment information for the periods presented below was as follows:
Offshore Pipeline TransportationSodium Minerals & Sulfur ServicesOnshore Facilities & TransportationMarine TransportationTotal
Three Months Ended June 30, 2021
Segment margin (a)$83,106 $38,194 $22,368 $8,468 $152,136 
Capital expenditures (b)$19,421 $80,560 $2,487 $11,157 $113,625 
Revenues:
External customers$73,221 $239,258 $144,406 $46,970 $503,855 
Intersegment (c)(2,171)1,515 656 
Total revenues of reportable segments$73,221 $237,087 $145,921 $47,626 $503,855 
Three Months Ended June 30, 2020
Segment margin (a)$75,148 $24,824 $21,215 $18,138 $139,325 
Capital expenditures (b)$1,983 $33,462 $829 $3,493 $39,767 
Revenues:
External customers$64,964 $194,543 $74,690 $54,270 $388,467 
Intersegment (c)(1,919)(531)2,450 
Total revenues of reportable segments$64,964 $192,624 $74,159 $56,720 $388,467 
Six Months Ended June 30, 2021
Segment Margin (a)$167,375 $81,914 $43,367 $15,577 $308,233 
Capital expenditures (b)$30,949 $90,598 $3,586 $22,871 $148,004 
Revenues:
External customers$137,605 $468,564 $332,556 $86,349 $1,025,074 
Intersegment (c)(4,190)2,582 1,608 
Total revenues of reportable segments$137,605 $464,374 $335,138 $87,957 $1,025,074 
Six Months Ended June 30, 2020
Segment Margin (a)$160,394 $61,765 $49,314 $37,140 $308,613 
Capital expenditures (b)$3,010 $48,437 $1,986 $17,725 $71,158 
Revenues:
External customers$143,393 $440,078 $231,489 $113,430 $928,390 
Intersegment (c)(4,064)(1,572)5,636 
Total revenues of reportable segments$143,393 $436,014 $229,917 $119,066 $928,390 
(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.
23

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
    Total assets by reportable segment were as follows:
June 30,
2021
December 31, 2020
Offshore pipeline transportation$2,152,939 $2,187,083 
Sodium minerals and sulfur services2,041,083 1,962,146 
Onshore facilities and transportation1,011,805 1,035,662 
Marine transportation710,870 711,058 
Other assets46,790 37,670 
Total consolidated assets$5,963,487 $5,933,619 

Reconciliation of total Segment Margin to net loss attributable to Genesis Energy, L.P.:
 Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
Total Segment Margin$152,136 $139,325 $308,233 $308,613 
Corporate general and administrative expenses(12,359)(24,867)(23,511)(31,359)
Depreciation, depletion, amortization and accretion(69,684)(82,580)(138,681)(158,558)
Interest expense(59,169)(51,618)(116,998)(106,583)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)
(7,692)(5,776)(16,548)(12,182)
Other non-cash items (2)
(14,683)(23,291)(33,127)8,777 
Distribution from unrestricted subsidiaries not included in income (3)
(17,500)(2,294)(35,000)(4,532)
Cancellation of debt income (4)
18,532 19,725 
Loss on extinguishment of debt (4)
(1,627)(23,480)
Differences in timing of cash receipts for certain contractual arrangements (5)
(6,446)(11,638)(6,745)(16,128)
Impairment expense (6)
(277,495)(277,495)
Provision for leased items no longer in use(58)(598)72 
Redeemable noncontrolling interest redemption value adjustments (7)
(5,766)(4,159)(10,557)(8,245)
Income tax expense(525)(795)(747)(430)
Net loss attributable to Genesis Energy, L.P.$(41,682)$(326,714)$(75,906)$(301,805)
(1)    Includes distributions attributable to the quarter and received during or promptly following such quarter.
(2)     The three and six months ended June 30, 2021 include a $14.3 million unrealized loss and $32.8 million unrealized loss, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and six months ended June 30, 2020 include a $21.8 million unrealized loss and $10.7 million unrealized gain, respectively, from the valuation of the embedded derivative. Refer to Note 16 for details.
(3)    The three and six months ended June 30, 2021 include $17.5 million and $35.0 million, respectively, in cash receipts not included in income associated with principal repayments on our previously owned NEJD pipeline. The three and six months ended June 30, 2020 include $2.3 million and $4.5 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 six months ended June 30, 2020.
(7) Includes PIK distributions attributable to the period and accretion on the redemption feature.
24

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
13. Transactions with Related Parties
The transactions with related parties were as follows:
 Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
Revenues:
Revenues from services and fees to Poseidon(1)
$3,242 $3,035 $7,028 $6,182 
Revenues from product sales to ANSAC71,329 48,695 139,284 121,774 
Costs and expenses:
Amounts paid to our CEO in connection with the use of his aircraft$165 $165 $330 $330 
Charges for services from Poseidon(1)
238 249 478 503 
Charges for services from ANSAC519 629 697 1,461 
(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 six months ended June 30, 2021 reflect $2.4 million and $4.7 million, respectively, associated with this agreement. Our revenues for the three and six months ended June 30, 2020 reflect $2.3 million and $4.6 million, respectively, of fees we earned through the provision of services under that agreement. At June 30, 2021 and December 31, 2020, Poseidon owed us $2.9 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 June 30, 2021, such amount is not material to us.
    Net Sales to ANSAC were $71.3 million and $139.3 million during the three and six months ended June 30, 2021 and were $48.7 million and $121.8 million during the three and six months ended June 30, 2020. The costs charged to us by ANSAC, included in sodium minerals and sulfur services operating costs, were $0.5 million and $0.7 million during the three and six months ended June 30, 2021 and were $0.6 million and $1.5 million during the three and six months ended June 30, 2020.
    
25

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Receivables from and payables to ANSAC as of June 30, 2021 and December 31, 2020 are as follows:
 June 30,December 31,
 20212020
Receivables:
ANSAC$66,178 $43,400 
Payables:
ANSAC$169 $470 

14. Supplemental Cash Flow Information
The following table provides information regarding the net changes in components of operating assets and liabilities.
 
 Six Months Ended
June 30,
 20212020
(Increase) decrease in:
Accounts receivable$(77,785)$178,509 
Inventories21,550 (44,394)
Deferred charges9,823 9,240 
Other current assets(4,835)(9,919)
Increase (decrease) in:
Accounts payable49,809 (93,080)
Accrued liabilities32,710 (20,838)
Net changes in components of operating assets and liabilities$31,272 $19,518 
Payments of interest and commitment fees were $78.0 million and $97.8 million for the six months ended June 30, 2021 and June 30, 2020, respectively. We capitalized interest of $1.4 million and $1.0 million during the six months ended June 30, 2021 and June 30, 2020, respectively.
At June 30, 2021 and June 30, 2020, we had incurred liabilities for fixed and intangible asset additions totaling $71.5 million and $25.5 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, which has the ability to be fully financed with our Alkali Holding preferred units, subject to compliance with the covenants contained in the agreements with GSO (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
26

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed.
    We have designated certain crude oil futures contracts as hedges of crude oil inventory due to our expectation that these contracts will be highly effective in hedging our exposure to fluctuations in crude oil prices during the period that we expect to hold that inventory. We account for these derivative instruments as fair value hedges under the accounting guidance. Changes in the fair value of these derivative instruments designated as fair value hedges are used to offset related changes in the fair value of the hedged crude oil inventory. Any hedge ineffectiveness in these fair value hedges and any amounts excluded from effectiveness testing are recorded as a gain or loss in the Unaudited Condensed Consolidated Statements of Operations.
    In accordance with NYMEX requirements, we fund the margin associated with our commodity derivative contracts traded on the NYMEX. The amount of the margin is adjusted daily based on the fair value of the commodity contracts. The margin requirements are intended to mitigate a party's exposure to market volatility and the associated contracting party risk. We offset fair value amounts recorded for our NYMEX derivative contracts against margin funding as required by the NYMEX in Current Assets - Other in our Unaudited Condensed Consolidated Balance Sheets.
    Additionally, we enter into swap arrangements. Our Alkali Business relies on natural gas to generate heat and electricity for operations. We use a combination of commodity price swap contracts and future purchase contracts to manage our exposure to fluctuations in natural gas prices. The swap contracts fix the basis differential between NYMEX Henry Hub and NW Rocky Mountain posted prices. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. We had 0 outstanding swap contracts at June 30, 2021.
    At June 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)92 
Weighted average contract price per bbl$70.71 $
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)204 10 
Weighted average contract price per bbl$70.75 $72.66 
Natural gas futures:
Contract volumes (10,000 MMBTU)15 15 
Weighted average contract price per MMBTU$3.55 $3.14 
Crude oil options:
Contract volumes (1,000 bbls)
Weighted average premium received/paid$5.59 $
Financial Statement Impacts
    Unrealized gains are subtracted from net income and unrealized losses are added to net income in determining cash flows from operating activities. To the extent that we have fair value hedges outstanding, the offsetting change recorded in the fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in margin deposits necessary to fund unrealized losses also affect cash flows from operating activities.
27

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following tables reflect the estimated fair value gain (loss) position of our derivatives at June 30, 2021 and December 31, 2020:
Fair Value of Derivative Assets and Liabilities
 Unaudited Condensed Consolidated Balance Sheets LocationFair Value
 June 30,
2021
 December 31, 2020
Asset Derivatives:
Commodity derivatives - futures and call options (undesignated hedges):
Gross amount of recognized assetsCurrent Assets - Other$65 $732 
Gross amount offset in the Unaudited Condensed Consolidated Balance SheetsCurrent Assets - Other(65)(732)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives$$
Natural Gas Swap (undesignated hedge)Current Assets - Other616 
Commodity derivatives - futures and call options (designated hedges):
Gross amount of recognized assetsCurrent Assets - Other$13 $1,022 
Gross amount offset in the Unaudited Condensed Consolidated Balance SheetsCurrent Assets - Other(13)(1,022)
Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives$$
Liability Derivatives:
Preferred Distribution Rate Reset Election (2)
Other long-term liabilities(85,154)(52,372)
Commodity derivatives - futures and call options (undesignated hedges):
Gross amount of recognized liabilities
Current Assets - Other (1)
$(605)$(2,114)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets
Current Assets - Other (1)
605 2,114 
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives$$
Commodity derivatives - futures and call options (designated hedges):
Gross amount of recognized liabilities
Current Assets - Other (1)
$(267)$(3,345)
Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets
Current Assets - Other (1)
267 3,073 
Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives$$(272)
 (1)    These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other.
(2) Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative.
 
Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists.  Accordingly, we also offset derivative assets and liabilities with amounts associated with cash margin.  Our exchange-traded derivatives are transacted through brokerage accounts and are subject to margin requirements as established by the respective exchange.  On a daily basis, our account equity (consisting of the sum of our cash balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin.  As of June 30, 2021, we had a net broker receivable of approximately $1.5 million (consisting of initial margin of $1.5 million and 0 variation margin).  As of December 31, 2020, we had a net broker receivable of approximately $3.4 million
28

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(consisting of initial margin of $3.3 million increased by $0.1 million of variation margin).  At June 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 June 30, 2021, the fair value of this embedded derivative was a liability of $85.2 million. See Note 10 for additional information regarding our Class A Convertible Preferred Units and the Rate Reset Election.
Effect on Operating Results 
Amount of Gain (Loss) Recognized in Income
 Unaudited Condensed Consolidated Statements of Operations LocationThree Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidanceOnshore facilities and transportation product costs$(1,563)$(10,936)$(7,460)$(10,207)
Contracts not considered hedges under accounting guidanceOnshore facilities and transportation product costs, Sodium minerals and sulfur services operating costs(1,779)(2,642)(5,700)(4,017)
Total commodity derivatives$(3,342)$(13,578)$(13,160)$(14,224)
Natural Gas SwapSodium minerals and sulfur services operating costs$30 $983 $(37)$551 
Preferred Distribution Rate Reset ElectionOther income (expense)$(14,344)$(21,839)$(32,782)$10,706 
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
(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.
29

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2021 and December 31, 2020. 
 Fair Value atFair Value at
June 30, 2021December 31, 2020
Recurring Fair Value MeasuresLevel 1Level 2Level 3Level 1Level 2Level 3
Commodity derivatives:
Assets$78 $$$1,754 $616 $
Liabilities$(872)$$$(5,459)$$
Preferred Distribution Rate Reset Election$$$(85,154)$$$(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:
 Six Months Ended
June 30,
2021
Balance as of December 31, 2020$(52,372)
Unrealized loss for the period included in earnings(32,782)
Balance as of June 30, 2021$(85,154)

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 June 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, credit spread, default probabilities, equity volatility and timing estimates which involve management judgment. Our equity volatility rate used to value our embedded derivative feature was 50% at June 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 a decrease in our discount yield compared to the preceding quarters, as well as the passage of time as we draw nearer to our coupon rate reset date in 2022, we recorded unrealized losses of $14.3 million and $32.8 million, respectively, for the three and six months ended June 30, 2021. During the second quarter of 2020, we recorded an unrealized loss of $21.8 million, while in the first quarter of 2020, we recorded an unrealized gain of $32.5 million, due to the significant changes and fluctuations in the energy industry credit markets and 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 June 30, 2021 our senior unsecured notes had a carrying value of $2.9 billion and fair value of $3.0 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.

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.
30

GENESIS ENERGY, L.P.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
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.

31

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 $41.7 million during the three months ended June 30, 2021 (the "2021 Quarter") compared to Net Loss Attributable to Genesis Energy, L.P. of $326.7 million during the three months ended June 30, 2020 (the "2020 Quarter").
Net Loss Attributable to Genesis Energy, L.P. in the 2020 Quarter was negatively impacted by impairment expense of $277.5 million associated with the rail logistics assets included within our onshore facilities and transportation segment and a one-time charge of approximately $13 million associated with certain severance and restructuring costs included within general and administrative costs and expenses. Additionally, the 2020 Quarter included cancellation of debt income of $18.5 million, which is recorded within "Other income (expense)" on the Unaudited Condensed Consolidated Statements of Operations, associated with the open market repurchase and extinguishment of certain of our senior unsecured notes.
Net Loss Attributable to Genesis Energy, L.P. in the 2021 Quarter was impacted, relative to the 2020 Quarter, by: (i) lower depreciation, depletion and amortization expense of $12.6 million primarily due to lower depreciation expense on our rail logistics assets as they were impaired during 2020; (ii) an unrealized (non-cash) loss from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units of $14.3 million in the 2021 Quarter compared to an unrealized (non-cash) loss of $21.8 million during the 2020 Quarter recorded within Other income (expense); and (iii) higher interest expense of $7.6 million (see "Other Costs, Interest, and Income Taxes" below for additional discussion regarding interest expense).
Cash flow from operating activities was $111.0 million for the 2021 Quarter compared to $62.6 million for the 2020 Quarter. This increase is primarily attributable to higher Segment Margin of $12.8 million in the 2021 Quarter and positive changes in working capital.
Available Cash before Reserves (as defined below in "Non-GAAP Financial Measures") to our common unitholders was $49.6 million for the 2021 Quarter, a decrease of $0.8 million, or 1.7%, 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 $152.1 million for the 2021 Quarter, an increase of $12.8 million, or 9%, 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 July 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 August 13, 2021 to unitholders of record at the close of business on July 30, 2021.


32

    

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 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.
    Beginning in March 2020, Covid-19 caused commodity prices to decline due to, among other things, reduced industrial activity and travel demand. Additionally, actions taken by OPEC and other oil exporting nations in that timeframe caused additional declines and volatility in the price of oil and gas. While we have seen some recovery in commodity prices since the beginning of the pandemic, primarily due to economies re-opening over time, there is still an element of volatility that we expect to continue at least for the near-term and possibly longer, due to the continued uncertainty of the pandemic, which could further negatively impact oil, natural gas, and petroleum products and industrial products.
    Due to the economic effects from commodity prices and Covid-19, demand and volumes throughout our businesses were negatively impacted throughout 2020 beginning in the second quarter. 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 in the second quarter of 2020. Additionally, during the 2021 Quarter, 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.

33

Results of Operations
Revenues and Costs and Expenses
    Our revenues for the 2021 Quarter increased $115.4 million, or 30%, from the 2020 Quarter and our total costs and expenses (excluding impairment expense) as presented on the Unaudited Condensed Consolidated Statements of Operations increased $89.1 million, or 23%, between the two periods, with a net increase to our operating income of $26.3 million.
The increase in our operating income during the 2021 Quarter is primarily driven by: (i) lower general and administrative costs as the 2020 Quarter included a one-time charge of approximately $13 million associated with certain severance and restructuring costs; and (ii) lower depreciation, depletion, and amortization of $12.6 million primarily due to lower depreciation expense on our rail logistics assets as they were impaired during 2020.
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 $66.07 per barrel in the 2021 Quarter, as compared to $27.85 per barrel in the 2020 Quarter. Impacts from Covid-19 along with actions taken by OPEC and other oil exporting nations beginning in early 2020 have caused significant and continued price volatility in oil and gas prices.
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, 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 December and January of the current year or periodically (often quarterly) throughout the current year, 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 75% 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
34

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 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
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
Offshore pipeline transportation$83,106 $75,148 $167,375 $160,394 
Sodium minerals and sulfur services38,194 24,824 81,914 61,765 
Onshore facilities and transportation22,368 21,215 43,367 49,314 
Marine transportation8,468 18,138 15,577 37,140 
Total Segment Margin$152,136 $139,325 $308,233 $308,613 

    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.
35

    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
June 30,
Six Months Ended
June 30,
 2021202020212020
Total Segment Margin$152,136 $139,325 $308,233 $308,613 
Corporate general and administrative expenses(12,359)(24,867)(23,511)(31,359)
Depreciation, depletion, amortization and accretion(69,684)(82,580)(138,681)(158,558)
Interest expense(59,169)(51,618)(116,998)(106,583)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)
(7,692)(5,776)(16,548)(12,182)
Other non-cash items (2)
(14,683)(23,291)(33,127)8,777 
Distribution from unrestricted subsidiaries not included in income (3)
(17,500)(2,294)(35,000)(4,532)
Cancellation of debt income— 18,532 — 19,725 
Provision for leased items no longer in use(58)(598)72 
Differences in timing of cash receipts for certain contractual arrangements (4)
(6,446)(11,638)(6,745)(16,128)
Loss on debt extinguishment (5)
— — (1,627)(23,480)
Impairment expense— (277,495)— (277,495)
Redeemable noncontrolling interest redemption value adjustments (6)
(5,766)(4,159)(10,557)(8,245)
Income tax expense(525)(795)(747)(430)
Net Loss Attributable to Genesis Energy, L.P.$(41,682)$(326,714)$(75,906)$(301,805)
(1)Includes distributions attributable to the quarter and received during or promptly following such quarter.
(2)The three and six months ended June 30, 2021 include a $14.3 million unrealized loss and a $32.8 million unrealized loss, respectively, from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units. The three and six months ended June 30, 2020 include a $21.8 million unrealized loss and $10.7 million unrealized gain, respectively, from the valuation of the embedded derivative.
(3)The three and six months ended June 30,2021 include $17.5 million and $35.0 million, respectively, and the three and six months ended June 30,2020 include $2.3 million and $4.5 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 six months ended June 30, 2021 includes the transaction costs and write-off of the unamortized issuance costs associated with the redemption of our remaining 2023 Notes. The six months ended June 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.

36

Offshore Pipeline Transportation Segment
    Operating results and volumetric data for our offshore pipeline transportation segment are presented below: 
 Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
Offshore crude oil pipeline revenue, excluding non-cash revenues$70,153 $61,003 $132,815 $130,584 
Offshore natural gas pipeline revenue, excluding non-cash revenues10,567 10,302 20,964 23,639 
Offshore pipeline operating costs, excluding non-cash expenses(19,328)(14,010)(37,334)(31,742)
Distributions from equity investments (1)
21,714 17,853 50,930 37,913 
Offshore pipeline transportation Segment Margin$83,106 $75,148 $167,375 $160,394 
Volumetric Data 100% basis:
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS204,963 196,962 160,940 219,572 
Poseidon265,359 253,341 302,180 266,261 
Odyssey125,170 114,006 131,771 133,375 
GOPL (2)
8,646 2,631 7,716 4,940 
Total crude oil offshore pipelines604,138 566,940 602,607 624,148 
Natural gas transportation volumes (MMBtus/d)347,123 329,876 336,456 375,283 
Volumetric Data net to our ownership interest (3):
Crude oil pipelines (average barrels/day unless otherwise noted):
CHOPS204,963 196,962 160,940 219,572 
Poseidon169,830 162,138 193,395 170,407 
Odyssey36,299 33,062 38,214 38,679 
GOPL (2)
8,646 2,631 7,716 4,940 
Total crude oil offshore pipelines419,738 394,793 400,265 433,598 
Natural gas transportation volumes (MMBtus/d)108,695 106,919 105,614 127,695 
(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)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.
(3)One of our wholly-owned subsidiaries (GEL Offshore Pipeline, LLC, or "GOPL") owns our undivided interest in the Eugene Island pipeline system.
Three Months Ended June 30, 2021 Compared with Three Months Ended June 30, 2020
    Offshore pipeline transportation Segment Margin for the 2021 Quarter increased $8.0 million, or 11%, from the 2020 Quarter primarily due to higher crude oil and natural gas transportation volumes. During the 2021 Quarter, we transported higher volumes 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. Additionally, we experienced less downtime during the 2021 Quarter, as the 2020 Quarter was impacted by extended downtime due to the economic environment from the Covid-19 pandemic and as a result of weather interruptions from Tropical Storm Cristobal.
Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
    Offshore pipeline transportation Segment Margin for the first six months of 2021 increased $7.0 million, or 4%, from the first six months of 2020, primarily as a result of 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
37

downstream to Poseidon. This increase in volumes was partially offset by lower volumes during 2021 on our CHOPS pipeline, as it was out of service through February 3, 2021 due to damage at a junction platform that the system goes up and over as a result of the 2020 hurricane season. On February 4, 2021, we placed the CHOPS pipeline back into service upon the installation of a bypass that allows our pipeline to operate around the junction platform. The lower CHOPS pipeline volumes were partially offset by increased distributions from our equity method investments, primarily associated with our 64% owned Poseidon oil pipeline system, as we were able to successfully divert CHOPS volumes to Poseidon 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
June 30,
Six Months Ended
June 30,
 2021202020212020
Volumes sold:
NaHS volumes (Dry short tons "DST")28,052 21,942 56,854 52,024 
Soda Ash volumes (short tons sold)772,132 594,810 1,534,952 1,417,057 
NaOH (caustic soda) volumes (DST)21,124 20,326 41,386 36,629 
Revenues (in thousands):
NaHS revenues, excluding non-cash revenues$30,134 $23,326 $60,270 $56,517 
NaOH (caustic soda) revenues9,799 8,644 18,206 16,085 
Revenues associated with Alkali Business173,779 141,898 341,103 318,134 
Other revenues893 462 1,823 1,105 
Total external segment revenues, excluding non-cash revenues(1)
$214,605 $174,330 $421,402 $391,841 
Segment Margin (in thousands)$38,194 $24,824 $81,914 $61,765 
Average index price for NaOH per DST(2)
$755 $698 $702 $673 
(1) Totals are for external revenues and costs prior to intercompany elimination upon consolidation.
(2) Source: IHS Chemical.
Three Months Ended June 30, 2021 Compared with Three Months Ended June 30, 2020
    Sodium minerals and sulfur services Segment Margin for the 2021 Quarter increased $13.4 million, or 54%. This increase is primarily due to higher soda ash volumes and favorable export pricing in our Alkali Business and higher NaHS sales volumes in our refinery services business during the 2021 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, despite a short halt in production for our long-wall move and certain other planned maintenance activities. Additionally, we saw slightly favorable export pricing in the 2021 Quarter relative to the 2020 Quarter and sequentially from the first quarter of 2021, which is evidence that the supply and demand balance is becoming more balanced. 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. 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 the 2021 Quarter due to improved volume 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.
Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
    Sodium minerals and sulfur services Segment Margin for the first six months of 2021 increased $20.1 million, or 33%, from the first six 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 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
38

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. 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 railcar and trucking fleets that support 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 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.

39

Operating results from our onshore facilities and transportation segment were as follows:
Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
Gathering, marketing, and logistics revenue$136,148 $59,830 $314,710 $195,137 
Crude oil and CO2 pipeline tariffs and revenues8,902 14,145 18,877 34,006 
Distributions from unrestricted subsidiaries not included in income (1)
17,500 2,294 35,000 4,532 
Crude oil and petroleum products costs, excluding unrealized gains and losses from derivative transactions(124,383)(42,783)(286,367)(154,277)
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses(15,431)(17,877)(30,697)(36,370)
Other(368)5,606 (8,156)6,286 
Segment Margin$22,368 $21,215 $43,367 $49,314 
Volumetric Data (average barrels per day unless otherwise noted):
Onshore crude oil pipelines:
Texas84,551 62,261 58,800 73,380 
Jay7,933 5,067 8,356 7,540 
Mississippi5,327 4,883 5,213 5,646 
Louisiana (2)
46,319 33,032 54,821 83,635 
Onshore crude oil pipelines total144,130 105,243 127,190 170,201 
CO2 pipeline (average Mcf/day):
Free State (3)
— 94,282 — 114,558 
Crude oil and petroleum products sales:
Total crude oil and petroleum products sales20,653 21,874 26,028 23,996 
Rail unload volumes3,556 4,150 21,803 49,095 
(1) The three and six months ended June 30, 2021 include cash payments received from our previously owned NEJD pipeline of $17.5 million and $35.0 million not included in income, respectively. The three and six months ended June 30, 2020 includes cash payments received from the NEJD pipeline of $5.2 million and $10.3 million, respectively, of which $2.3 million and $4.5 million, respectively, were not included in income.
(2) Total daily volume for the three and six months ended June 30, 2021 includes 39,875 and 32,397 barrels per day of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines. Total daily volume for the three and six months ended June 30, 2020 includes 28,851 and 36,586 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 June 30, 2021 Compared with Three Months Ended June 30, 2020
    Onshore facilities and transportation Segment Margin for the 2021 Quarter increased $1.2 million, or 5%. This increase is primarily due to higher cash receipts received during the 2021 Quarter from Denbury of approximately $12.3 million associated with our previously owned NEJD pipeline as a result of our agreement reached during the fourth quarter of 2020. This increase was partially offset by: (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 the 2021 Quarter by our main customer; and (ii) the divestiture of our Free State pipeline during the fourth quarter of 2020, which contributed positively to Segment Margin in the 2020 Quarter.
Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
    Onshore facilities and transportation Segment Margin for the first six months of 2021 decreased $5.9 million, or 12%, from the first six months of 2020. This decrease was primarily due to lower rail unload and crude oil pipeline volumes associated with our Baton Rouge corridor assets, in addition to our customer utilizing certain of its prepaid transportation credits that accumulated during 2020, and the divestiture of our Free State pipeline during the fourth quarter of 2020, which contributed
40

positively to Segment Margin during the six months ended June 30, 2020. These decreases were partially offset by higher cash receipts received during the six months ended June 30, 2021 from Denbury of approximately $24.7 million associated with our previously owned NEJD pipeline as a result of our agreement reached during the fourth quarter 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
June 30,
Six Months Ended
June 30,
 2021202020212020
Revenues (in thousands):
Inland freight revenues$18,231 $25,805 $35,746 $53,377 
Offshore freight revenues16,504 22,268 31,030 43,359 
Other rebill revenues (1)
12,891 8,647 21,181 22,330 
Total segment revenues$47,626 $56,720 $87,957 $119,066 
Operating costs, excluding non-cash charges for long-term incentive compensation and other non-cash expenses (in thousands)$39,158 $38,582 $72,380 $81,926 
Segment Margin (in thousands)$8,468 $18,138 $15,577 $37,140 
Fleet Utilization: (2)
Inland Barge Utilization81.2 %87.6 %76.6 %90.5 %
Offshore Barge Utilization96.8 %96.8 %96.3 %98.1 %
(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 June 30, 2021 Compared with Three Months Ended June 30, 2020
    Marine transportation Segment Margin for the 2021 Quarter decreased $9.7 million, or 53%, from the 2020 Quarter. This decrease is primarily attributable to lower utilization and day rates in our inland business during the 2021 Quarter and lower rates in our offshore barge operation, including our M/T American Phoenix tanker. During the 2021 Quarter, we began to see sequential improvement in the offshore barge spot market pricing, but we expect to see continued pressure on our utilization, and to an extent, the 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. 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 from their cyclical lows.
41

Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
    Marine transportation Segment Margin for the first six months of 2021 decreased $21.6 million, or 58%, from the first six months of 2020. This decrease is primarily attributable to lower utilization and day rates in our inland business during the 2021 Quarter and lower rates in our offshore barge operation, including our M/T American Phoenix tanker. We expect to see continued pressure on our utilization, and to an extent, the 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. 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 from their cyclical lows. We also re-contracted our M/T American Phoenix tanker beginning in the 2021 Quarter for one year, but at a lower rate than our previous long-term contract that ended during the second half of 2020.

Other Costs, Interest, and Income Taxes
    General and administrative expenses
Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
General and administrative expenses not separately identified below:
Corporate$10,368 $23,364 $19,789 $34,157 
Segment1,036 1,073 2,087 2,138 
Long-term incentive compensation expense882 955 1,962 (1,530)
Third party costs related to business development activities and growth projects621 21 735 21 
Total general and administrative expenses$12,907 $25,413 $24,573 $34,786 
Three Months Ended June 30, 2021 Compared with Three Months Ended June 30, 2020
Total general and administrative expenses for the 2021 Quarter decreased by $12.5 million. This decrease is primarily due to the 2020 Quarter including a one-time charge of approximately $13 million related to certain severance and restructuring expenses.
Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
Total general and administrative expenses for the first six months of 2021 decreased by $10.2 million primarily due to the 2020 Quarter including a one-time charge of approximately $13 million related to certain severance and restructuring expenses. This 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.

    Depreciation, depletion, and amortization expense
Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
Depreciation and depletion expense$64,852 $75,930 $128,466 $146,135 
Amortization expense2,689 4,190 5,361 8,342 
Total depreciation, depletion and amortization expense$67,541 $80,120 $133,827 $154,477 

Three Months Ended June 30, 2021 Compared with Three Months Ended June 30, 2020
    Total depreciation, depletion, and amortization expense for the 2021 Quarter decreased by $12.6 million. This decrease is primarily due to lower depreciation expense associated with our rail logistics assets in the 2021 Quarter 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 in the 2021 Quarter.
42


Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
Total depreciation, depletion, and amortization expense for the first six months of 2021 decreased by $20.7 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 in the 2021 Quarter.
Impairment Expense
During the three and six months ended June 30, 2020, we recorded impairment expenses of $277.5 million associated with the rail logistics assets included within our onshore facilities and transportation segment. We had no impairment expense during 2021.

Interest expense, net
Three Months Ended
June 30,
Six Months Ended
June 30,
 2021202020212020
 (in thousands)(in thousands)
Interest expense, senior secured credit facility (including commitment fees)$5,812 $9,664 $13,243 $20,409 
Interest expense, senior unsecured notes51,859 40,202 100,194 82,560 
Amortization of debt issuance costs and premium2,255 2,200 4,970 4,591 
Capitalized interest(757)(448)(1,409)(977)
Net interest expense$59,169 $51,618 $116,998 $106,583 

Three Months Ended June 30, 2021 Compared with Three Months Ended June 30, 2020
    Net interest expense for the 2021 Quarter increased $7.6 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.
Six Months Ended June 30, 2021 Compared with Six Months Ended June 30, 2020
Net interest expense for the first six months of 2021 increased by $10.4 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.
The increase in interest expenses 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 2021.
    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.

43

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 5.85x through June 30, 2021, 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 of 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 June 30, 2021, our balance sheet and liquidity position remained strong, which included $530.5 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 June 30, 2021, our long-term debt totaled approximately $3,343.2 million, which is a reduction of $50.6 million sequentially from December 31, 2020, and consisted of $415.7 million outstanding under our senior secured credit facility, net (including $19.6 million borrowed under the inventory sublimit tranche) and $2,927.5 million of senior unsecured notes, net. Our senior unsecured notes, net balance is comprised of $338.6 million carrying amount due on June 15, 2024, $529.8 million carrying amount due October 2025, $356.0 million carrying amount due May 2026, $992.6 million carrying value due January 15, 2027, and $710.5 million carrying amount due February 1, 2028. We remain focused on continuing to reduce our leverage.
    On September 23, 2019, we announced the GOP. We entered into agreements with GSO for the purchase of up to approximately $350 million of preferred units of Alkali Holdings. The proceeds received from GSO 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 GSO 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
44

GSO, which was accounted for as issuance costs. Additionally, the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. 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.
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 six months ended June 30, 2021 were $188.2 million compared to $152.2 million for the six months ended June 30, 2020. This increase is primarily attributable to positive changes in working capital during 2021 and transactions costs incurred during 2020 associated with the tender and redemption of our previously held 2022 Notes.
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
45

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.
Capital Expenditures
    A summary of our expenditures for fixed assets, business and other asset acquisitions for 2021 and 2020 are as follows:
Six Months Ended
June 30,
 20212020
 (in thousands)
Capital expenditures for fixed and intangible assets:
Maintenance capital expenditures:
Offshore pipeline transportation assets$7,371 $2,097 
Sodium minerals and sulfur services assets16,032 12,051 
Marine transportation assets22,871 17,725 
Onshore facilities and transportation assets3,453 1,618 
Information technology systems190 99 
Total maintenance capital expenditures49,917 33,590 
Growth capital expenditures:
Offshore pipeline transportation assets23,578 913 
Sodium minerals and sulfur services assets74,566 36,386 
Marine transportation assets— — 
Onshore facilities and transportation assets133 368 
Information technology systems4,211 2,515 
Total growth capital expenditures102,488 40,182 
Total capital expenditures for fixed and intangible assets$152,405 $73,772 
    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. We entered into agreements with GSO for the purchase of up to approximately $350 million of preferred units (or 350,000 preferred units) of Alkali Holdings. The proceeds received from GSO 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 GSO 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 GSO. As part of the amendment, the commitment period was increased to four years, and the total commitment of GSO was increased to, subject to compliance with the covenants contained in the agreements with GSO, up to $351,750,000 preferred units (or 351,750 preferred units) in Alkali Holdings. The Alkali Holdings preferred unitholders receive PIK distributions in lieu of cash distributions during the new anticipated construction period. As of June 30, 2021 we had issued 201,705 Alkali Holdings preferred units. The expansion is expected to increase our production at the Granger facilities by approximately 750,000 tons per year.
    Except for the GOP, we do not anticipate spending material growth capital expenditures on any 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 incurred maintenance capital expenditures in our offshore transportation segment to replace certain pipeline and platform equipment and complete 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.
46

    Distributions to Unitholders
    On August 13, 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 August 13, 2021 to unitholders of record at the close of business on July 30, 2021.
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 SheetsGenesis Energy, L.P. and Guarantor Subsidiaries
June 30, 2021December 31, 2020
ASSETS:
Current assets$368,126 $313,328 
Fixed assets, net3,082,195 3,115,492 
Non-current assets826,504 861,230 
LIABILITIES AND CAPITAL:(1)
Current liabilities381,264 266,688 
Non-current liabilities3,694,962 3,710,044 
Class A Convertible Preferred Units790,115 790,115 
47

Statements of OperationsGenesis Energy, L.P. and Guarantor Subsidiaries
Six Months Ended
June 30, 2021
Twelve Months Ended
December 31. 2020
Revenues$679,668 $1,156,428 
Operating costs644,271 1,421,674 
Operating income (loss)35,397 (265,246)
Loss before income taxes(82,629)(408,717)
Net loss(1)
(83,366)(409,951)
Less: Accumulated distributions to Class A Convertible Preferred Units(37,368)(74,736)
Net loss available to common unitholders(120,734)(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 $63.2 million and $95.7 million of net intercompany receivables due to Genesis Energy, L.P. and the Guarantor Subsidiaries from the Non-Guarantor Subsidiaries as of June 30, 2021 and December 31, 2020, respectively.
Non-GAAP Financial Measure Reconciliations
    For definitions and discussion of our Non-GAAP financial measures refer to the "Non-GAAP Financial Measures" as later discussed and defined.
Available Cash before Reserves for the periods presented below was as follows:
 Three Months Ended
June 30,
 20212020
(in thousands)
Net loss attributable to Genesis Energy, L.P.$(41,682)$(326,714)
Income tax expense525 795 
Depreciation, depletion, amortization and accretion69,684 82,580 
Impairment expense— 277,495 
Plus (minus) Select Items, net47,440 40,809 
Maintenance capital utilized (1)
(13,300)(9,900)
Cash tax expense(195)(150)
Distributions to preferred unitholders(18,684)(18,684)
Redeemable noncontrolling interest redemption value adjustments (2)
5,766 4,159 
Available Cash before Reserves$49,554 $50,390 
(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 $23.8 million and $13.0 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.
48

 Three Months Ended
June 30,
 20212020
 (in thousands)
I.Applicable to all Non-GAAP Measures
Differences in timing of cash receipts for certain contractual arrangements (1)
$6,446 $11,638 
Distribution from unrestricted subsidiaries not included in income (2)
17,500 2,294 
Certain non-cash items:
Unrealized losses on derivative transactions excluding fair value hedges, net of changes in inventory value (3)
14,750 21,108 
Adjustment regarding equity investees (4)
7,692 5,776 
Other(67)2,183 
             Sub-total Select Items, net46,321 42,999 
II.Applicable only to Available Cash before Reserves
Certain transaction costs (5)
621 21 
Other498 (2,211)
Total Select Items, net (6)
$47,440 $40,809 
(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 $2.3 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 $14.3 million unrealized loss from the valuation of the embedded derivative associated with our Class A Convertible Preferred Units and the 2020 Quarter includes a $21.8 million unrealized loss 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, transition, and financing transactions incurred in advance of acquisition.
(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
49

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.
50

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 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
51

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 GSO 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;
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;
52

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.
53

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.
54

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.
55

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  
3.3  
3.4
3.5  
3.6
3.7  
3.8  
3.9
3.10
4.1  
*4.2
*4.3
*22.1
*31.1  
*31.2  
*32  
*95
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.
104Cover Page Interactive Data File (formatted as Inline XBRL).
*Filed herewith
56

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

57