UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
(Mark one)
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| ☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended: SeptemberJune 30, 20222023
or
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to
Commission File Number: 333-186007
Commission File Number: 333-186007-07 PBF HOLDING COMPANY LLC
PBF FINANCE CORPORATION
(Exact name of registrant as specified in its charter) | | | | | | | | | | | |
| Delaware | | 27-2198168 |
| Delaware | | 45-2685067 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| | |
| One Sylvan Way, Second Floor | | |
| Parsippany | New Jersey | | 07054 |
| (Address of principal executive offices) | | (Zip Code) |
(973) 455-7500
(Registrants’ telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act. | | | | | | | | |
| Title of each class | Trading Symbol | Name of each exchange on which registered |
| N/A | N/A | N/A |
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.
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| PBF Holding Company LLC | ☐ | Yes | ☒ | No |
| PBF Finance Corporation | ☐ | Yes | ☒ | No |
(Note: The registrant is a voluntary filer of reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 and has filed during the preceding 12 months all reports it would have been required to file by Section 13 or 15(d) of the Securities Exchange Act of 1934 if the registrant had been subject to one of such Sections.)
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).
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| PBF Holding Company LLC | ☒ | Yes | ☐ | No |
| PBF Finance Corporation | ☒ | Yes | ☐ | 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.
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| Large accelerated
filer | | Accelerated filer | | Non-accelerated filer | | Smaller reporting
company | Emerging growth company |
| | | (Do not check if a
smaller reporting
company) | |
| PBF Holding Company LLC | ☐ | | ☐ | | ☒ | | ☐ | ☐ |
| PBF Finance Corporation | ☐ | | ☐ | | ☒ | | ☐ | ☐ |
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.
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| PBF Holding Company LLC | ☐ | Yes | ☐ | No |
| PBF Finance Corporation | ☐ | Yes | ☐ | No |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
| | | | | | | | | | | | | | |
| PBF Holding Company LLC | ☐ | Yes | ☒ | No |
| PBF Finance Corporation | ☐ | Yes | ☒ | No |
PBF Holding Company LLC has no common stock outstanding. As of October 28, 2022,August 4, 2023, 100% of the membership interests of PBF Holding Company LLC were owned by PBF Energy Company LLC, and PBF Finance Corporation had 100 shares of common stock outstanding, all of which were held by PBF Holding Company LLC.
PBF Finance Corporation meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this form with the reduced disclosure format.
PBF HOLDING COMPANY LLC
FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBERJUNE 30, 20222023
TABLE OF CONTENTS
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| CAUTIONARY NOTE REGARDING FORWARD LOOKING STATEMENTS | |
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EXPLANATORY NOTE
This combined Quarterly Report on Form 10-Q for the quarter ended SeptemberJune 30, 20222023 (this “Form 10-Q”) is filed by PBF Holding Company LLC (“PBF Holding”) and PBF Finance Corporation (“PBF Finance”). PBF Holding is a wholly-owned subsidiary of PBF Energy Company LLC (“PBF LLC”) and is the parent company for PBF LLC’s refinery operating subsidiaries. PBF Finance is a wholly-owned subsidiary of PBF Holding. PBF Holding is an indirect subsidiary of PBF Energy Inc. (“PBF Energy”), which is the sole managing member of, and owner of an equity interest representing approximately 99.3% of the outstanding economic interests in PBF LLC as of SeptemberJune 30, 2022.2023. PBF Energy operates and controls all of the business and affairs and consolidates the financial results of PBF LLC and its subsidiaries. PBF Logistics GP LLC (“PBF GP”) is a wholly-owned subsidiary of PBF LLC and the general partner of PBF Logistics LP (“PBFX”), which is an affiliate of PBF Holding. PBF Holding, together with its consolidated subsidiaries, owns and operates oil refineries and related facilities in North America.
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This combined Quarterly Report on Form 10-Q contains certain “forward-looking statements” of expected future developments that involve risks and uncertainties. You can identify forward-looking statements because they contain words such as “believes,” “expects,” “may,” “should,” “seeks,” “approximately,” “intends,” “plans,” “estimates,” or “anticipates” or similar expressions that relate to our strategy, plans or intentions. All statements we make relating to our estimated and projected earnings, margins, costs, expenditures, cash flows, growth rates and financial results or to our expectations regarding future industry trends are forward-looking statements. In addition, we, through our senior management, from time to time make forward-looking public statements concerning our expected future operations and performance and other developments. These forward-looking statements are subject to risks and uncertainties that may change at any time, and, therefore, our actual results may differ materially from those that we expected. We derive many of our forward-looking statements from our operating budgets and forecasts, which are based on many detailed assumptions. While we believe that our assumptions are reasonable, we caution that it is very difficult to predict the impact of known factors, and, of course, it is impossible for us to anticipate all factors that could affect our actual results.
Important factors that could cause actual results to differ materially from our expectations, which we refer to as "cautionary statements," are disclosed under "Management's Discussion and Analysis of Financial Condition and Results of Operations" and elsewhere in this Form 10-Q, the Annual Report on Form 10-K for the year ended December 31, 20212022 of PBF Holding and PBF Finance, which we refer to as our 20212022 Annual Report on Form 10-K, and in our other filings with the U.S. Securities and Exchange Commission.Commission (“SEC”). All forward-looking information in this Quarterly Report on Form 10-Q and subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements. Some of the factors that we believe could affect our results include:
•supply, demand, prices and other market conditions for our products or crude oil, including volatility in commodity prices or constraints arising from federal, state or local governmental actions or environmental and/or social activists that reduce crude oil production or availability in the regions in which we operate our pipelines and facilities;
•rate of inflation and its impacts on supply and demand, pricing, and supply chain disruption;
•the effects related to, or resulting from Russia’s military action in Ukraine, including the imposition of additional sanctions and export controls, as well as the broader impacts to financial markets and the global macroeconomic and geopolitical environment;
•the effectiveness of our crude oil sourcing strategies, including our crude by rail strategy and related commitments;
•our obligation to buy Renewable Identification Numbers (“RINs”) and market risks related to the volatility in the price of RINs required to comply with the Renewable Fuel Standard (“RFS”) and greenhouse gas (“GHG”) emission credits required to comply with various GHG emission programs, such as Assembly Bill 32 (“AB 32”);
•our ability to operate our businesses efficiently, manage capital expenditures and costs (including general and administrative expenses) and generate earnings and cash flow;
•our expectations with respect to our capital spending and turnaround projects;
•the continued effect of the coronavirus (“COVID-19”) pandemic, including resurgences and variants of the virus, as well as related governmental and consumer responses on our business, financial condition and results of operations;
•the impact of current and future laws, rulings and governmental regulations, including restrictions on the exploration and/or production of crude oil in the state of California, the implementation of rules and regulations regarding transportation of crude oil by rail or in response to the potential impacts of climate change, decarbonization and future energy transition;
•adverse impacts related to legislation by the federal government lifting the restrictions on exporting U.S. crude oil or subjecting us to trade and sanctions laws, which change frequently as a result of foreign policy developments, and which may necessitate changes to our crude oil acquisition activities;
•our ability to target and execute expense reduction measures and achieve opportunities to improve our liquidity, including continued repurchases of our outstanding debt securities or otherwise further reducing our debt, and/or potential sales of non-operating assets or other real property;
•political pressure and influence of environmental groups and other stakeholders on decisions and policies related to the refining and processing of crude oil and refined products, and the related adverse impacts from changes in our regulatory environment, such as the effects of compliance with AB 32, or from actions taken by environmental interest groups;
•the risk of cyber-attacks;
•our increased dependence on technology;
•the effects of competition in our markets;
•our ability to make acquisitions or investments, including in renewable diesel production, on any announced time frame or at all, and to realize the benefits from such acquisitions or investments;
•liabilities arising from recent acquisitions or investments, that are unforeseen or exceededexceed our expectation;expectations;
•our expectations and timing with respect to our acquisition activity;
•adverse developments in our relationship with both our key employees and unionized employees;
•our indebtedness, including the impact of potential downgrades to our corporate credit rating andand/or unsecured notes;
•changes in currency exchange rates, interest rates and capital costs;
•restrictive covenants in our indebtedness that may adversely affect our operational flexibility;
•counterparty credit and performance risk exposure related to our supply and any inventory intermediation arrangements;
•termination of our third amended and restated inventory intermediation agreement (“Third Inventory Intermediation Agreement”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”) which is scheduled to expire in December 2024 and could have a material adverse effect on our liquidity, as we would be required to finance our crude oil, intermediate and refined products inventory covered by the agreement. Additionally, we are obligated to repurchase from J. Aron certain crude oil, intermediates and finished products (the “J. Aron Products”) upon termination of the agreement;
•our assumptions regarding payments arising under PBF Energy’s tax receivable agreement entered with the PBF LLC Series A and PBF LLC Series B unitholders and other arrangements relating to PBF Energy;
•the impact of disruptions to crude or feedstock supply to any of our refineries, including disruptions related to PBFX or with third-party logistics infrastructure or operations, including pipeline, marine and rail transportation; and
•any decisions we continue to make with respect to our energy-related logistics assets that may be transferred to PBFX.
We caution you that the foregoing list of important factors may not contain all of the material factors that are important to you. In addition, in light of these risks and uncertainties, the matters referred to in the forward-looking statements contained in this Form 10-Q may not in fact occur. Accordingly, investors should not place undue reliance on those statements.
Our forward-looking statements speak only as of the date of this Form 10-Q. Except as required by applicable law, including the securities laws of the United States, we do not intend to update or revise any forward-looking statements. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the foregoing.
PART I – FINANCIAL INFORMATION
Item 1. Financial Statements
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited, in millions) | | | September 30,
2022 | | December 31,
2021 | | June 30,
2023 | | December 31,
2022 |
| ASSETS | ASSETS | | | | ASSETS | | | |
| Current assets: | Current assets: | | Current assets: | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 1,851.5 | | | $ | 1,305.7 | | Cash and cash equivalents | $ | 1,496.8 | | | $ | 2,153.9 | |
| | Accounts receivable | Accounts receivable | 1,625.1 | | | 1,272.0 | | Accounts receivable | 1,352.2 | | | 1,451.7 | |
| Accounts receivable - affiliate | Accounts receivable - affiliate | 4.5 | | | 4.1 | | Accounts receivable - affiliate | 16.0 | | | 6.3 | |
| | Inventories | Inventories | 2,689.5 | | | 2,505.1 | | Inventories | 2,832.3 | | | 2,763.6 | |
| | Prepaid and other current assets | Prepaid and other current assets | 340.3 | | | 71.7 | | Prepaid and other current assets | 150.5 | | | 119.0 | |
| Total current assets | Total current assets | 6,510.9 | | | 5,158.6 | | Total current assets | 5,847.8 | | | 6,494.5 | |
| Property, plant and equipment, net | Property, plant and equipment, net | 4,368.2 | | | 4,114.8 | | Property, plant and equipment, net | 4,057.9 | | | 4,601.8 | |
| Lease right of use assets - third party | Lease right of use assets - third party | 685.6 | | | 717.0 | | Lease right of use assets - third party | 791.7 | | | 678.3 | |
| Lease right of use assets - affiliate | Lease right of use assets - affiliate | 419.2 | | | 485.4 | | Lease right of use assets - affiliate | 370.8 | | | 421.6 | |
| | Deferred charges and other assets, net | Deferred charges and other assets, net | 904.4 | | | 813.8 | | Deferred charges and other assets, net | 1,092.4 | | | 954.0 | |
| Total assets | Total assets | $ | 12,888.3 | | | $ | 11,289.6 | | Total assets | $ | 12,160.6 | | | $ | 13,150.2 | |
| LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | | | | LIABILITIES AND EQUITY | | | |
| Current liabilities: | Current liabilities: | | Current liabilities: | |
| Accounts payable | Accounts payable | $ | 908.5 | | | $ | 906.3 | | Accounts payable | $ | 629.0 | | | $ | 847.5 | |
| Accounts payable - affiliate | Accounts payable - affiliate | 41.0 | | | 61.7 | | Accounts payable - affiliate | 38.5 | | | 38.2 | |
| Accrued expenses | Accrued expenses | 3,736.6 | | | 2,728.3 | | Accrued expenses | 3,337.7 | | | 3,691.0 | |
| Current operating lease liabilities - third party | Current operating lease liabilities - third party | 62.4 | | | 64.8 | | Current operating lease liabilities - third party | 120.8 | | | 60.5 | |
| Current operating lease liabilities - affiliate | Current operating lease liabilities - affiliate | 97.2 | | | 90.7 | | Current operating lease liabilities - affiliate | 108.9 | | | 104.5 | |
| | Deferred revenue | Deferred revenue | 71.9 | | | 40.3 | | Deferred revenue | 74.8 | | | 37.5 | |
| | Total current liabilities | Total current liabilities | 4,917.6 | | | 3,892.1 | | Total current liabilities | 4,309.7 | | | 4,779.2 | |
| | Long-term debt | Long-term debt | 1,447.7 | | | 3,673.3 | | Long-term debt | 1,441.5 | | | 1,434.9 | |
| | Deferred tax liabilities | Deferred tax liabilities | 24.9 | | | 24.2 | | Deferred tax liabilities | 21.2 | | | 21.0 | |
| Long-term operating lease liabilities - third party | Long-term operating lease liabilities - third party | 553.7 | | | 570.3 | | Long-term operating lease liabilities - third party | 613.1 | | | 551.8 | |
| Long-term operating lease liabilities - affiliate | Long-term operating lease liabilities - affiliate | 322.0 | | | 394.7 | | Long-term operating lease liabilities - affiliate | 261.9 | | | 317.2 | |
| Long-term financing lease liabilities - third party | Long-term financing lease liabilities - third party | 60.8 | | | 70.6 | | Long-term financing lease liabilities - third party | 52.1 | | | 57.9 | |
| Other long-term liabilities | Other long-term liabilities | 325.7 | | | 251.0 | | Other long-term liabilities | 314.3 | | | 371.1 | |
| Total liabilities | Total liabilities | 7,652.4 | | | 8,876.2 | | Total liabilities | 7,013.8 | | | 7,533.1 | |
| Commitments and contingencies (Note 7) | Commitments and contingencies (Note 7) | | Commitments and contingencies (Note 7) | |
| Equity: | Equity: | | Equity: | |
| PBF Holding Company LLC equity | PBF Holding Company LLC equity | | PBF Holding Company LLC equity | |
| Member’s equity | Member’s equity | 2,938.7 | | | 2,870.2 | | Member’s equity | 2,764.3 | | | 2,959.7 | |
| Retained earnings (accumulated deficit) | 2,266.9 | | | (489.3) | | |
| Accumulated other comprehensive income | 18.1 | | | 20.3 | | |
| Retained earnings | | Retained earnings | 2,374.3 | | | 2,649.6 | |
| Accumulated other comprehensive loss | | Accumulated other comprehensive loss | (4.4) | | | (4.4) | |
| Total PBF Holding Company LLC equity | Total PBF Holding Company LLC equity | 5,223.7 | | | 2,401.2 | | Total PBF Holding Company LLC equity | 5,134.2 | | | 5,604.9 | |
| Noncontrolling interest | Noncontrolling interest | 12.2 | | | 12.2 | | Noncontrolling interest | 12.6 | | | 12.2 | |
| Total equity | Total equity | 5,235.9 | | | 2,413.4 | | Total equity | 5,146.8 | | | 5,617.1 | |
| Total liabilities and equity | Total liabilities and equity | $ | 12,888.3 | | | $ | 11,289.6 | | Total liabilities and equity | $ | 12,160.6 | | | $ | 13,150.2 | |
See notes to condensed consolidated financial statements.
5
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited, in millions)
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| Three Months Ended June 30, | | Six Months Ended June 30, |
| 2023 | | 2022 | | 2023 | | 2022 |
| Revenues | $ | 9,148.4 | | | $ | 14,064.0 | | | $ | 18,433.9 | | | $ | 23,192.2 | |
| Cost and expenses: | | | | | | | |
| Cost of products and other | 7,988.2 | | | 11,455.8 | | | 15,867.9 | | | 19,733.3 | |
| Operating expenses (excluding depreciation and amortization expense as reflected below) | 571.4 | | | 613.8 | | | 1,320.4 | | | 1,209.4 | |
| Depreciation and amortization expense | 133.0 | | | 110.9 | | | 265.9 | | | 219.8 | |
| Cost of sales | 8,692.6 | | | 12,180.5 | | | 17,454.2 | | | 21,162.5 | |
| General and administrative expenses (excluding depreciation and amortization expense as reflected below) | 100.8 | | | 145.9 | | | 157.9 | | | 195.2 | |
| Depreciation and amortization expense | 2.3 | | | 1.9 | | | 4.2 | | | 3.8 | |
| Change in fair value of contingent consideration, net | (16.6) | | | 77.6 | | | (32.9) | | | 127.7 | |
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| Loss (gain) on sale of assets | 0.2 | | | 0.2 | | | (1.4) | | | 0.3 | |
| Total cost and expenses | 8,779.3 | | | 12,406.1 | | | 17,582.0 | | | 21,489.5 | |
| Income from operations | 369.1 | | | 1,657.9 | | | 851.9 | | | 1,702.7 | |
| Other income (expense): | | | | | | | |
| Interest expense, net | (15.1) | | | (75.4) | | | (30.0) | | | (143.6) | |
| Change in fair value of catalyst obligations | 0.5 | | | 7.2 | | | 1.2 | | | 2.3 | |
| Gain on extinguishment of debt | — | | | 3.8 | | | — | | | 3.8 | |
| Other non-service components of net periodic benefit cost | 0.1 | | | 2.2 | | | 0.4 | | | 4.4 | |
| Income before income taxes | 354.6 | | | 1,595.7 | | | 823.5 | | | 1,569.6 | |
| Income tax benefit | — | | | (1.2) | | | (0.6) | | | (9.3) | |
| Net income | 354.6 | | | 1,596.9 | | | 824.1 | | | 1,578.9 | |
| Less: net income (loss) attributable to noncontrolling interests | 0.1 | | | (0.6) | | | 0.4 | | | (1.7) | |
| Net income attributable to PBF Holding Company LLC | $ | 354.5 | | | $ | 1,597.5 | | | $ | 823.7 | | | $ | 1,580.6 | |
See notes to condensed consolidated financial statements.
6
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONSCOMPREHENSIVE INCOME
(unaudited, in millions)
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| Three Months Ended June 30, | | Six Months Ended June 30, |
| 2023 | | 2022 | | 2023 | | 2022 |
| Net income | $ | 354.6 | | | $ | 1,596.9 | | | $ | 824.1 | | | $ | 1,578.9 | |
| Other comprehensive income (loss): | | | | | | | |
| Unrealized loss on available for sale securities | (0.5) | | | (0.6) | | | (0.1) | | | (1.7) | |
| Net gain on pension and other post-retirement benefits | 0.1 | | | — | | | 0.1 | | | 0.1 | |
| Total other comprehensive income (loss) | (0.4) | | | (0.6) | | | — | | | (1.6) | |
| Comprehensive income | 354.2 | | | 1,596.3 | | | 824.1 | | | 1,577.3 | |
| Less: comprehensive income (loss) attributable to noncontrolling interests | 0.1 | | | (0.6) | | | 0.4 | | | (1.7) | |
| Comprehensive income attributable to PBF Holding Company LLC | $ | 354.1 | | | $ | 1,596.9 | | | $ | 823.7 | | | $ | 1,579.0 | |
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| Three Months Ended September 30, | | Nine Months Ended September 30, |
| 2022 | | 2021 | | 2022 | | 2021 |
| Revenues | $ | 12,752.3 | | | $ | 7,173.3 | | | $ | 35,944.5 | | | $ | 18,969.7 | |
| Cost and expenses: | | | | | | | |
| Cost of products and other | 10,490.2 | | | 6,445.8 | | | 30,223.5 | | | 16,880.7 | |
| Operating expenses (excluding depreciation and amortization expense as reflected below) | 620.1 | | | 507.6 | | | 1,829.5 | | | 1,430.1 | |
| Depreciation and amortization expense | 119.1 | | | 103.0 | | | 338.9 | | | 310.0 | |
| Cost of sales | 11,229.4 | | | 7,056.4 | | | 32,391.9 | | | 18,620.8 | |
| General and administrative expenses (excluding depreciation and amortization expense as reflected below) | 161.7 | | | 59.7 | | | 356.9 | | | 150.5 | |
| Depreciation and amortization expense | 2.0 | | | 3.4 | | | 5.8 | | | 10.1 | |
| Change in fair value of contingent consideration | 3.0 | | | (0.7) | | | 130.7 | | | 23.6 | |
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| Loss (gain) on sale of assets | — | | | 0.2 | | | 0.3 | | | (0.4) | |
| Total cost and expenses | 11,396.1 | | | 7,119.0 | | | 32,885.6 | | | 18,804.6 | |
| Income from operations | 1,356.2 | | | 54.3 | | | 3,058.9 | | | 165.1 | |
| Other income (expense): | | | | | | | |
| Interest expense, net | (43.1) | | | (71.5) | | | (186.7) | | | (211.0) | |
| Change in fair value of catalyst obligations | (2.6) | | | 17.8 | | | (0.3) | | | 13.6 | |
| (Loss) gain on extinguishment of debt | (69.9) | | | 60.3 | | | (66.1) | | | 60.3 | |
| Other non-service components of net periodic benefit cost | 2.2 | | | 2.0 | | | 6.6 | | | 5.9 | |
| Income before income taxes | 1,242.8 | | | 62.9 | | | 2,812.4 | | | 33.9 | |
| Income tax expense (benefit) | 10.4 | | | (2.0) | | | 1.1 | | | (16.9) | |
| Net income | 1,232.4 | | | 64.9 | | | 2,811.3 | | | 50.8 | |
| Less: net income (loss) attributable to noncontrolling interests | 0.3 | | | (0.1) | | | (1.4) | | | 2.3 | |
| Net income attributable to PBF Holding Company LLC | $ | 1,232.1 | | | $ | 65.0 | | | $ | 2,812.7 | | | $ | 48.5 | |
See notes to condensed consolidated financial statements.
7
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOMECHANGES IN EQUITY
(unaudited, in millions)
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended September 30, | | Nine Months Ended September 30, |
| 2022 | | 2021 | | 2022 | | 2021 |
| Net income | $ | 1,232.4 | | | $ | 64.9 | | | $ | 2,811.3 | | | $ | 50.8 | |
| Other comprehensive income (loss): | | | | | | | |
| Unrealized loss on available for sale securities | (0.9) | | | — | | | (2.6) | | | (0.5) | |
| Net gain on pension and other post-retirement benefits | 0.3 | | | 0.2 | | | 0.4 | | | 0.6 | |
| Total other comprehensive income (loss) | (0.6) | | | 0.2 | | | (2.2) | | | 0.1 | |
| Comprehensive income | 1,231.8 | | | 65.1 | | | 2,809.1 | | | 50.9 | |
| Less: comprehensive income (loss) attributable to noncontrolling interests | 0.3 | | | (0.1) | | | (1.4) | | | 2.3 | |
| Comprehensive income attributable to PBF Holding Company LLC | $ | 1,231.5 | | | $ | 65.2 | | | $ | 2,810.5 | | | $ | 48.6 | |
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| | Member’s Equity | | Accumulated
Other
Comprehensive
Income (Loss) | | Retained Earnings (Accumulated Deficit) | | Noncontrolling
Interest | | Total
Equity |
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| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
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| Balance, March 31, 2023 | $ | 2,991.2 | | | $ | (4.0) | | | $ | 2,460.6 | | | $ | 12.5 | | | $ | 5,460.3 | |
| Member distributions | — | | | — | | | (440.8) | | | — | | | (440.8) | |
| Capital contributions from PBF LLC | 610.0 | | | — | | | — | | | — | | | 610.0 | |
| Distribution of assets to PBF LLC | (844.1) | | | — | | | — | | | — | | | (844.1) | |
| Stock-based compensation | 7.2 | | | — | | | — | | | — | | | 7.2 | |
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| Comprehensive income (loss) | — | | | (0.4) | | | 354.5 | | | 0.1 | | | 354.2 | |
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| Balance, June 30, 2023 | $ | 2,764.3 | | | $ | (4.4) | | | $ | 2,374.3 | | | $ | 12.6 | | | $ | 5,146.8 | |
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| Balance, March 31, 2022 | $ | 2,892.8 | | | $ | 19.3 | | | $ | (510.0) | | | $ | 11.1 | | | $ | 2,413.2 | |
| Member distributions | — | | | — | | | (7.7) | | | — | | | (7.7) | |
| Capital contributions from PBF LLC | 9.0 | | | — | | | — | | | — | | | 9.0 | |
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| Stock-based compensation | 6.6 | | | — | | | — | | | — | | | 6.6 | |
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| Comprehensive income (loss) | — | | | (0.6) | | | 1,597.5 | | | (0.6) | | | 1,596.3 | |
| Other | — | | | — | | | — | | | 0.4 | | | 0.4 | |
| Balance, June 30, 2022 | $ | 2,908.4 | | | $ | 18.7 | | | $ | 1,079.8 | | | $ | 10.9 | | | $ | 4,017.8 | |
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See notes to condensed consolidated financial statements.
8
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(unaudited, in millions)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Member’s Equity | | Accumulated
Other
Comprehensive
Income (Loss) | | Retained Earnings (Accumulated Deficit) | | Noncontrolling
Interest | | Total
Equity |
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| Balance, June 30, 2022 | $ | 2,908.4 | | | $ | 18.7 | | | $ | 1,079.8 | | | $ | 10.9 | | | $ | 4,017.8 | |
| Member distributions | — | | | — | | | (45.0) | | | — | | | (45.0) | |
| Capital contributions from PBF LLC | 25.0 | | | — | | | — | | | — | | | 25.0 | |
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| Stock-based compensation | 5.3 | | | — | | | — | | | — | | | 5.3 | |
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| Comprehensive income (loss) | — | | | (0.6) | | | 1,232.1 | | | 0.3 | | | 1,231.8 | |
| Other | — | | | — | | | — | | | 1.0 | | | 1.0 | |
| Balance, September 30, 2022 | $ | 2,938.7 | | | $ | 18.1 | | | $ | 2,266.9 | | | $ | 12.2 | | | $ | 5,235.9 | |
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| Balance, June 30, 2021 | $ | 2,841.1 | | | $ | (6.2) | | | $ | (741.9) | | | $ | 12.3 | | | $ | 2,105.3 | |
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| Capital contributions from PBF LLC | 9.1 | | | — | | | — | | | — | | | 9.1 | |
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| Stock-based compensation | 5.5 | | | — | | | — | | | — | | | 5.5 | |
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| Comprehensive income (loss) | — | | | 0.2 | | | 65.0 | | | (0.1) | | | 65.1 | |
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| Balance, September 30, 2021 | $ | 2,855.7 | | | $ | (6.0) | | | $ | (676.9) | | | $ | 12.2 | | | $ | 2,185.0 | |
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See notes to condensed consolidated financial statements.
9
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(unaudited, in millions)
| | | | Member’s Equity | | Accumulated
Other
Comprehensive
Income (Loss) | | Retained Earnings (Accumulated Deficit) | | Noncontrolling
Interest | | Total
Equity | | Member’s Equity | | Accumulated
Other
Comprehensive
Income (Loss) | | Retained Earnings (Accumulated Deficit) | | Noncontrolling
Interest | | Total
Equity |
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| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 2,959.7 | | | $ | (4.4) | | | $ | 2,649.6 | | | $ | 12.2 | | | $ | 5,617.1 | |
| Member distributions | | Member distributions | — | | | — | | | (1,099.0) | | | — | | | (1,099.0) | |
| Capital contributions from PBF LLC | | Capital contributions from PBF LLC | 635.0 | | | — | | | — | | | — | | | 635.0 | |
| Distribution of assets to PBF LLC | | Distribution of assets to PBF LLC | (844.1) | | | — | | | — | | | — | | | (844.1) | |
| Stock-based compensation expense | | Stock-based compensation expense | 13.7 | | | — | | | — | | | — | | | 13.7 | |
| | Comprehensive income | | Comprehensive income | — | | | — | | | 823.7 | | | 0.4 | | | 824.1 | |
| | Balance, June 30, 2023 | | Balance, June 30, 2023 | $ | 2,764.3 | | | $ | (4.4) | | | $ | 2,374.3 | | | $ | 12.6 | | | $ | 5,146.8 | |
| | | Member’s Equity | | Accumulated
Other
Comprehensive
Income (Loss) | | Retained Earnings (Accumulated Deficit) | | Noncontrolling
Interest | | Total
Equity | | | | | | | | | | |
| Balance, December 31, 2021 | Balance, December 31, 2021 | | Balance, December 31, 2021 | $ | 2,870.2 | | | $ | 20.3 | | | $ | (489.3) | | | $ | 12.2 | | | $ | 2,413.4 | |
| Member distributions | Member distributions | — | | | — | | | (56.5) | | | — | | | (56.5) | | Member distributions | — | | | — | | | (11.5) | | | — | | | (11.5) | |
| Capital contributions from PBF LLC | Capital contributions from PBF LLC | 50.0 | | | — | | | — | | | — | | | 50.0 | | Capital contributions from PBF LLC | 25.0 | | | — | | | — | | | — | | | 25.0 | |
| | Stock-based compensation expense | 18.5 | | | — | | | — | | | — | | | 18.5 | | |
| Stock-based compensation | | Stock-based compensation | 13.2 | | | — | | | — | | | — | | | 13.2 | |
| | Comprehensive income (loss) | Comprehensive income (loss) | — | | | (2.2) | | | 2,812.7 | | | (1.4) | | | 2,809.1 | | Comprehensive income (loss) | — | | | (1.6) | | | 1,580.6 | | | (1.7) | | | 1,577.3 | |
| Other | Other | — | | | — | | | — | | | 1.4 | | | 1.4 | | Other | — | | | — | | | — | | | 0.4 | | | 0.4 | |
| Balance, September 30, 2022 | $ | 2,938.7 | | | $ | 18.1 | | | $ | 2,266.9 | | | $ | 12.2 | | | $ | 5,235.9 | | |
| | | Balance, December 31, 2020 | $ | 2,809.7 | | | $ | (6.1) | | | $ | (723.4) | | | $ | 10.6 | | | $ | 2,090.8 | | |
| Member distributions | — | | | — | | | (2.0) | | | — | | | (2.0) | | |
| Capital contributions from PBF LLC | 28.0 | | | — | | | — | | | — | | | 28.0 | | |
| Distribution of assets to PBF LLC | (0.3) | | | — | | | — | | | — | | | (0.3) | | |
| Stock-based compensation | 18.3 | | | — | | | — | | | — | | | 18.3 | | |
| | Comprehensive income | — | | | 0.1 | | | 48.5 | | | 2.3 | | | 50.9 | | |
| Other | — | | | — | | | — | | | (0.7) | | | (0.7) | | |
| Balance, September 30, 2021 | $ | 2,855.7 | | | $ | (6.0) | | | $ | (676.9) | | | $ | 12.2 | | | $ | 2,185.0 | | |
| Balance, June 30, 2022 | | Balance, June 30, 2022 | $ | 2,908.4 | | | $ | 18.7 | | | $ | 1,079.8 | | | $ | 10.9 | | | $ | 4,017.8 | |
See notes to condensed consolidated financial statements.
109
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited, in millions) | | | Nine Months Ended September 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2023 | | 2022 |
| Cash flows from operating activities: | Cash flows from operating activities: | | | | Cash flows from operating activities: | | | |
| Net income | Net income | $ | 2,811.3 | | | $ | 50.8 | | Net income | $ | 824.1 | | | $ | 1,578.9 | |
| Adjustments to reconcile net income to net cash provided by operating activities: | Adjustments to reconcile net income to net cash provided by operating activities: | | Adjustments to reconcile net income to net cash provided by operating activities: | |
| Depreciation and amortization | Depreciation and amortization | 360.0 | | | 331.4 | | Depreciation and amortization | 280.7 | | | 233.5 | |
| Stock-based compensation | Stock-based compensation | 20.7 | | | 20.1 | | Stock-based compensation | 18.9 | | | 14.5 | |
| Change in fair value of catalyst obligations | Change in fair value of catalyst obligations | 0.3 | | | (13.6) | | Change in fair value of catalyst obligations | (1.2) | | | (2.3) | |
| Deferred income taxes | Deferred income taxes | 0.7 | | | (15.6) | | Deferred income taxes | 0.1 | | | (9.3) | |
| Non-cash change in inventory repurchase obligations | Non-cash change in inventory repurchase obligations | (21.1) | | | 46.0 | | Non-cash change in inventory repurchase obligations | 8.5 | | | (3.4) | |
| Non-cash lower of cost or market inventory adjustment | — | | | (669.6) | | |
| Change in fair value of contingent consideration | 130.7 | | | 23.6 | | |
| Loss (gain) on extinguishment of debt | 66.1 | | | (60.3) | | |
| | Change in fair value of contingent consideration, net | | Change in fair value of contingent consideration, net | (32.9) | | | 127.7 | |
| Gain on extinguishment of debt | | Gain on extinguishment of debt | — | | | (3.8) | |
| Pension and other post-retirement benefit costs | Pension and other post-retirement benefit costs | 35.7 | | | 38.0 | | Pension and other post-retirement benefit costs | 23.9 | | | 23.8 | |
| | Loss (gain) on sale of assets | 0.3 | | | (0.4) | | |
| (Gain) loss on sale of assets | | (Gain) loss on sale of assets | (1.4) | | | 0.3 | |
| | Changes in operating assets and liabilities: | Changes in operating assets and liabilities: | | Changes in operating assets and liabilities: | |
| Accounts receivable | Accounts receivable | (353.1) | | | (549.3) | | Accounts receivable | 99.5 | | | (690.0) | |
| Due to/from affiliates | Due to/from affiliates | (21.2) | | | 11.0 | | Due to/from affiliates | (9.5) | | | (14.8) | |
| Inventories | Inventories | (184.4) | | | (475.6) | | Inventories | (68.7) | | | (471.3) | |
| Prepaid and other current assets | Prepaid and other current assets | (268.6) | | | (65.2) | | Prepaid and other current assets | (36.4) | | | (140.3) | |
| Accounts payable | Accounts payable | (14.1) | | | 34.8 | | Accounts payable | (202.1) | | | 398.5 | |
| Accrued expenses | Accrued expenses | 938.2 | | | 1,564.4 | | Accrued expenses | (322.5) | | | 1,100.0 | |
| Deferred revenue | Deferred revenue | 31.6 | | | (5.5) | | Deferred revenue | 37.3 | | | 42.8 | |
| Other assets and liabilities | Other assets and liabilities | (1.8) | | | (80.1) | | Other assets and liabilities | (19.4) | | | (28.6) | |
| Net cash provided by operating activities | Net cash provided by operating activities | $ | 3,531.3 | | | $ | 184.9 | | Net cash provided by operating activities | $ | 598.9 | | | $ | 2,156.2 | |
| | Cash flows from investing activities: | Cash flows from investing activities: | | Cash flows from investing activities: | |
| | Expenditures for property, plant and equipment | Expenditures for property, plant and equipment | (386.9) | | | (135.1) | | Expenditures for property, plant and equipment | (442.0) | | | (223.4) | |
| Expenditures for deferred turnaround costs | Expenditures for deferred turnaround costs | (240.3) | | | (64.6) | | Expenditures for deferred turnaround costs | (268.0) | | | (166.8) | |
| Expenditures for other assets | Expenditures for other assets | (51.9) | | | (20.6) | | Expenditures for other assets | (35.0) | | | (43.6) | |
| | Proceeds from sale of assets | | Proceeds from sale of assets | 4.4 | | | — | |
| | Net cash used in investing activities | Net cash used in investing activities | $ | (679.1) | | | $ | (220.3) | | Net cash used in investing activities | $ | (740.6) | | | $ | (433.8) | |
|
See notes to condensed consolidated financial statements.
1110
PBF HOLDING COMPANY LLC
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)
(unaudited, in millions) | | | Nine Months Ended September 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2023 | | 2022 |
| Cash flows from financing activities: | Cash flows from financing activities: | | | | Cash flows from financing activities: | | | |
| Contributions from PBF LLC | Contributions from PBF LLC | $ | 50.0 | | | $ | 28.0 | | Contributions from PBF LLC | $ | 635.0 | | | $ | 25.0 | |
| Distributions to members | Distributions to members | (56.6) | | | (2.0) | | Distributions to members | (1,099.0) | | | (11.6) | |
| | Distributions to T&M and Collins shareholders | — | | | (0.7) | | |
| | | Repurchase of 2028 6.00% Senior Notes | Repurchase of 2028 6.00% Senior Notes | (21.1) | | | (69.7) | | Repurchase of 2028 6.00% Senior Notes | — | | | (21.1) | |
| Repurchase of 2025 7.25% Senior Notes | Repurchase of 2025 7.25% Senior Notes | (4.8) | | | (21.2) | | Repurchase of 2025 7.25% Senior Notes | — | | | (4.8) | |
| Redemption of 2025 9.25% Senior Secured Notes | (1,307.4) | | | — | | |
| Repayments of PBF Rail Term Loan | — | | | (5.5) | | |
| | Proceeds from revolver borrowings | 400.0 | | | — | | |
| | Payment of contingent consideration | | Payment of contingent consideration | (80.1) | | | — | |
| | Repayments of revolver borrowings | Repayments of revolver borrowings | (1,300.0) | | | — | | Repayments of revolver borrowings | — | | | (900.0) | |
| Settlement of precious metal catalyst obligations | (37.3) | | | (18.5) | | |
| | | Payments on financing leases | Payments on financing leases | (8.5) | | | (10.7) | | Payments on financing leases | (5.8) | | | (5.7) | |
| Proceeds from insurance premium financing | Proceeds from insurance premium financing | 10.5 | | | 7.0 | | Proceeds from insurance premium financing | 35.0 | | | 32.4 | |
| Deferred financing costs and other, net | Deferred financing costs and other, net | (31.2) | | | 0.4 | | Deferred financing costs and other, net | (0.5) | | | (32.2) | |
| Net cash used in financing activities | Net cash used in financing activities | $ | (2,306.4) | | | $ | (92.9) | | Net cash used in financing activities | $ | (515.4) | | | $ | (918.0) | |
| | Net change in cash and cash equivalents | Net change in cash and cash equivalents | 545.8 | | | (128.3) | | Net change in cash and cash equivalents | (657.1) | | | 804.4 | |
| Cash and cash equivalents, beginning of period | Cash and cash equivalents, beginning of period | 1,305.7 | | | 1,570.1 | | Cash and cash equivalents, beginning of period | 2,153.9 | | | 1,305.7 | |
| Cash and cash equivalents, end of period | Cash and cash equivalents, end of period | $ | 1,851.5 | | | $ | 1,441.8 | | Cash and cash equivalents, end of period | $ | 1,496.8 | | | $ | 2,110.1 | |
| | Supplemental cash flow disclosures | Supplemental cash flow disclosures | | Supplemental cash flow disclosures | |
| Non-cash activities: | Non-cash activities: | | Non-cash activities: | |
| Distribution of assets to PBF Energy Company LLC | | Distribution of assets to PBF Energy Company LLC | $ | 844.1 | | | $ | — | |
| Accrued and unpaid capital expenditures | Accrued and unpaid capital expenditures | $ | 106.3 | | | $ | 64.5 | | Accrued and unpaid capital expenditures | 108.6 | | | 118.9 | |
| Assets acquired or remeasured under operating and financing leases | Assets acquired or remeasured under operating and financing leases | 36.7 | | | (126.5) | | Assets acquired or remeasured under operating and financing leases | 174.8 | | | 31.3 | |
| Cash paid during the period for: | Cash paid during the period for: | | Cash paid during the period for: | |
| Interest (net of capitalized interest of $15.8 million and $5.3 million in 2022 and 2021, respectively) | $ | 183.1 | | | $ | 173.9 | | |
| Interest (net of capitalized interest of $28.1 million and $9.2 million in 2023 and 2022, respectively) | | Interest (net of capitalized interest of $28.1 million and $9.2 million in 2023 and 2022, respectively) | $ | 46.0 | | | $ | 131.0 | |
| Income taxes | Income taxes | 1.1 | | 0.8 | | Income taxes | 1.4 | | 0.8 | |
See notes to condensed consolidated financial statements.
1211
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
1. DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION
Description of the Business
PBF Holding Company LLC (“PBF Holding”), a Delaware limited liability company, and PBF Finance Corporation (“PBF Finance”), a wholly-owned subsidiary of PBF Holding, together with the Company’s consolidated subsidiaries, owns and operates oil refineries and related facilities in North America. PBF Holding is a wholly-owned subsidiary of PBF Energy Company LLC (“PBF LLC”). PBF Energy Inc. (“PBF Energy”) is the sole managing member of, and owner of an equity interest representing approximately 99.3% of the outstanding economic interest in, PBF LLC as of SeptemberJune 30, 2022.2023. PBF Investments LLC, Toledo Refining Company LLC, Paulsboro Refining Company LLC (“PRC”), Delaware City Refining Company LLC (“DCR”), Chalmette Refining, L.L.C. (“Chalmette Refining”), PBF Energy Western Region LLC, Torrance Refining Company LLC, Torrance Logistics Company LLC and Martinez Refining Company LLC are PBF LLC’s principal operating subsidiaries and are all wholly-owned subsidiaries of PBF Holding. Collectively, PBF Holding and its consolidated subsidiaries are referred to hereinafter as the “Company”.
PBF Logistics GP LLC (“PBF GP”) serves as the general partner of PBF Logistics LP (“PBFX”). PBF GP is wholly-owned by PBF LLC. In a series of transactions, PBF Holding has distributed certain assets to PBF LLC, which in turn contributed those assets to PBFX (as described in “Note 6 - Related Party Transactions”).
On June 27, 2023, the Company distributed to PBF LLC, which in turn contributed to St. Bernard Renewables LLC (“SBR”), approximately $739.8 million in assets related to the renewable diesel facility co-located with the Company’s Chalmette refinery in Louisiana. The Company has no interest in SBR, which is jointly owned by a subsidiary of PBF LLC and its partner, Eni Sustainable Mobility US Inc., a subsidiary of Eni SpA. Additionally, the Company distributed to PBF LLC, which in turn contributed to one of its subsidiaries, Chalmette Refining Service Company LLC (“CRSC”), approximately $103.8 million in assets. The Company has no interest in CRSC, which is owned by PBF LLC.
Basis of Presentation
The unaudited condensed consolidated financial information furnished herein reflects all adjustments (consisting of normal recurring accruals) which are, in the opinion of management, considered necessary for a fair presentation of the financial position and the results of operations and cash flows of the Company for the periods presented. All intercompany accounts and transactions have been eliminated in consolidation. These unaudited Condensed Consolidated Financial Statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. These interim Condensed Consolidated Financial Statements should be read in conjunction with the PBF Holding and PBF Finance financial statements included in the Annual Report on Form 10-K for the year ended December 31, 2021.2022. The results of operations for the three and ninesix months ended SeptemberJune 30, 20222023 are not necessarily indicative of the results to be expected for the full year.
Recently Adopted Accounting Guidance
In March 2020, the Financial Accounting Standards Board issued Accounting Standard Update (“ASU”) 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the effects of reference rate reform on financial reporting”. The amendments in this ASU provide optional guidance to alleviate the burden in accounting for reference rate reform, by allowing certain expedients and exceptions in applying GAAP to contracts, hedging relationships and other transactions affected by the expected market transition from London Interbank Offered Rate (“LIBOR”) and other interbank rates. The Company’s adoption of this guidance did not have, and is not anticipated to have, a material impact on its Consolidated Financial Statements and related disclosures.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
2. CURRENT EXPECTED CREDIT LOSSES
Credit Losses
The Company has exposure to credit losses primarily through its sales of refined products. The Company evaluates creditworthiness on an individual customer basis. The Company utilizes a financial review model for purposes of evaluating creditworthiness which is based on information from financial statements and credit reports. The financial review model enables the Company to assess the customer’s risk profile and determine credit limits on the basis of their financial strength, including but not limited to, their liquidity, leverage, debt serviceability, longevity and how they pay their bills. The Company may require security in the form of letters of credit or cash payments in advance of product delivery for certain customers that are deemed higher risk.
The Company’s payment terms on its trade receivables are relatively short, generally 30 days or less for a substantial majority of its refined products. As a result, the Company’s collection risk is mitigated to a certain extent by the fact that sales are collected in a relatively short period of time, allowing for the ability to reduce exposure on defaults if collection issues are identified. Notwithstanding, the Company reviews each customer’s credit risk profile at least annually or more frequently if warranted.
The Company performs a quarterly allowance for doubtful accounts analysis to assess whether an allowance needs to be recorded for any outstanding trade receivables. In estimating credit losses, management reviews accounts that are past due, have known disputes or have experienced any negative credit events that may result in future collectability issues. There was no allowance for doubtful accounts recorded as of SeptemberJune 30, 20222023 or December 31, 2021.2022.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
3. INVENTORIES
Inventories consisted of the following:
| | September 30, 2022 | |
| June 30, 2023 | | June 30, 2023 |
| (in millions) | (in millions) | Titled Inventory | | Inventory Intermediation Agreement | | Total | (in millions) | Titled Inventory | | Inventory Intermediation Agreement | | Total |
| Crude oil and feedstocks | Crude oil and feedstocks | $ | 1,069.3 | | | $ | 144.4 | | | $ | 1,213.7 | | Crude oil and feedstocks | $ | 1,200.1 | | | $ | 140.2 | | | $ | 1,340.3 | |
| Refined products and blendstocks | Refined products and blendstocks | 1,089.3 | | | 239.7 | | | 1,329.0 | | Refined products and blendstocks | 1,254.2 | | | 93.9 | | | 1,348.1 | |
| Warehouse stock and other | Warehouse stock and other | 146.8 | | | — | | | 146.8 | | Warehouse stock and other | 143.9 | | | — | | | 143.9 | |
| | $ | 2,305.4 | | | $ | 384.1 | | | $ | 2,689.5 | | | $ | 2,598.2 | | | $ | 234.1 | | | $ | 2,832.3 | |
| Lower of cost or market adjustment | Lower of cost or market adjustment | — | | | — | | | — | | Lower of cost or market adjustment | — | | | — | | | — | |
| Total inventories | Total inventories | $ | 2,305.4 | | | $ | 384.1 | | | $ | 2,689.5 | | Total inventories | $ | 2,598.2 | | | $ | 234.1 | | | $ | 2,832.3 | |
| | December 31, 2021 | |
| December 31, 2022 | | December 31, 2022 |
| (in millions) | (in millions) | Titled Inventory | | Inventory Intermediation Agreement | | Total | (in millions) | Titled Inventory | | Inventory Intermediation Agreement | | Total |
| Crude oil and feedstocks | Crude oil and feedstocks | $ | 953.5 | | | $ | 151.4 | | | $ | 1,104.9 | | Crude oil and feedstocks | $ | 1,195.2 | | | $ | 140.9 | | | $ | 1,336.1 | |
| Refined products and blendstocks | Refined products and blendstocks | 964.6 | | | 293.8 | | | 1,258.4 | | Refined products and blendstocks | 1,244.7 | | | 40.9 | | | 1,285.6 | |
| Warehouse stock and other | Warehouse stock and other | 141.8 | | | — | | | 141.8 | | Warehouse stock and other | 141.9 | | | — | | | 141.9 | |
| | $ | 2,059.9 | | | $ | 445.2 | | | $ | 2,505.1 | | | $ | 2,581.8 | | | $ | 181.8 | | | $ | 2,763.6 | |
| Lower of cost or market adjustment | Lower of cost or market adjustment | — | | | — | | | — | | Lower of cost or market adjustment | — | | | — | | | — | |
| Total inventories | Total inventories | $ | 2,059.9 | | | $ | 445.2 | | | $ | 2,505.1 | | Total inventories | $ | 2,581.8 | | | $ | 181.8 | | | $ | 2,763.6 | |
On October 25, 2021, PBF Holding and its subsidiaries, DCR, PRC and Chalmette Refining (collectively, the “PBF Entities”), entered into a thirdan inventory intermediation agreement (as amended and restated inventory intermediation agreement (thefrom time to time, the “Third Inventory Intermediation Agreement”) with J. Aron & Company, a subsidiary of The Goldman Sachs Group, Inc. (“J. Aron”), pursuant to which the terms of the existing inventory intermediation agreements were amended and restated in their entirety, including, among other things, pricing and an extension of terms. The Third Inventory Intermediation Agreement extends the term to December 31, 2024, which term may be further extended by mutual consent of the parties to December 31, 2025. On May 25, 2022, the PBF Entities entered into an amendment of the Third Inventory Intermediation Agreement to amend certain provisions thereof that related to and were impacted by amendments made on May 25, 2022 to the Revolving Credit Agreement (as defined below).
Pursuant to the Third Inventory Intermediation Agreement, J. Aron will continue to purchasepurchased and holdheld title to certain inventory, including crude oil, intermediate and certain finished products (the “J. Aron Products”) purchased or produced by the Paulsboro and Delaware City refineries (and, at the election of the PBF Entities, the Chalmette refinery) (the “Refineries”) and delivered into storage tanks at the Refineries (the “Storage Tanks”). The J. Aron Products arewere sold back to the Company as the J. Aron Products arewere discharged out of the Storage Tanks. These purchases and sales arewere settled daily, and pricing iswas trued-up monthly at the market prices related to those J. Aron Products. These transactions arewere considered to be made in contemplation of each other and, accordingly, dodid not result in the recognition of a sale when title passespassed from the Refineries to J. Aron. Additionally, J. Aron hashad the right to store the J. Aron Products purchased in Storage Tanks under the Third Inventory Intermediation Agreement and will retainretained these storage rights for the term of the agreement. PBF Holding continues to market and sell the J. Aron Products independently to third parties. On June 28, 2023, the PBF Entities entered into a second amendment of the Third Inventory Intermediation Agreement to amend certain provisions in order to allow for the early termination of the Third Inventory Intermediation Agreement effective as of July 31, 2023. Following the early termination, the Company owns all of the inventory previously held by J. Aron.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
At SeptemberAs of June 30, 2023 and December 31, 2022 there was no lower of cost or market adjustment recorded as the replacement value of inventories exceeded the last-in, first-out (“LIFO”) carrying value. There was no lower of cost or market (“LCM”) inventory reserve at September 30, 2022 or December 31, 2021.
At September 30, 2021, the replacement value of inventories exceeded the LIFO carrying value. During the nine months ended September 30, 2021, the Company recorded an adjustment to value its inventories to the lower of cost or market which increased income from operations by $669.6 million, reflecting no LCM inventory reserve at September 30, 2021 in comparison with an LCM inventory reserve of $669.6 million at December 31, 2020.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
4. ACCRUED EXPENSES
Accrued expenses consisted of the following:
| | (in millions) | (in millions) | September 30, 2022 | | December 31, 2021 | (in millions) | June 30, 2023 | | December 31, 2022 |
| Inventory-related accruals | Inventory-related accruals | $ | 1,625.7 | | | $ | 959.9 | | Inventory-related accruals | $ | 1,659.5 | | | $ | 1,417.4 | |
| Renewable energy credit and emissions obligations (a) | Renewable energy credit and emissions obligations (a) | 1,233.8 | | | 953.9 | | Renewable energy credit and emissions obligations (a) | 792.3 | | | 1,361.1 | |
| Accrued salaries and benefits | 180.3 | | | 57.1 | | |
| Inventory intermediation agreement (b) | Inventory intermediation agreement (b) | 121.6 | | | 280.1 | | Inventory intermediation agreement (b) | 177.8 | | | 98.3 | |
| Accrued transportation costs | Accrued transportation costs | 114.4 | | | 91.0 | | Accrued transportation costs | 159.8 | | | 127.3 | |
| Excise and sales tax payable | Excise and sales tax payable | 109.2 | | | 112.3 | | Excise and sales tax payable | 137.9 | | | 123.8 | |
| Contingent consideration | 93.9 | | | — | | |
| Accrued salaries and benefits | | Accrued salaries and benefits | 114.4 | | | 172.9 | |
| Accrued refinery maintenance and support costs | | Accrued refinery maintenance and support costs | 65.2 | | | 48.1 | |
| Accrued utilities | Accrued utilities | 86.6 | | | 73.0 | | Accrued utilities | 51.8 | | | 105.4 | |
| Accrued capital expenditures | Accrued capital expenditures | 49.3 | | | 62.6 | | Accrued capital expenditures | 45.5 | | | 85.7 | |
| Accrued refinery maintenance and support costs | 37.3 | | | 55.8 | | |
| Contingent consideration | | Contingent consideration | 29.4 | | | 81.6 | |
| Accrued interest | Accrued interest | 20.8 | | | 32.8 | | Accrued interest | 20.2 | | | 20.1 | |
| Environmental liabilities | Environmental liabilities | 14.3 | | | 14.3 | | Environmental liabilities | 13.7 | | | 14.1 | |
| Current finance lease liabilities | Current finance lease liabilities | 11.6 | | | 11.1 | | Current finance lease liabilities | 11.7 | | | 11.7 | |
| | Customer deposits | 3.2 | | | 3.5 | | |
| Other | Other | 34.6 | | | 20.9 | | Other | 58.5 | | | 23.5 | |
| Total accrued expenses | Total accrued expenses | $ | 3,736.6 | | | $ | 2,728.3 | | Total accrued expenses | $ | 3,337.7 | | | $ | 3,691.0 | |
__________________________
(a) The Company is subject to obligations to purchase Renewable Identification Numbers (“RINs”) required to comply with the Renewable Fuel Standard. The Company’s overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by Environmental Protection Agency. To the degree the Company is unable to blend the required amount of biofuels to satisfy its RINs obligation, RINs must be purchased on the open market to avoid penalties and fines. The Company records its RINs obligation on a net basis in Accrued expenses when its RINs liability is greater than the amount of RINs earned and purchased in a given period and in Prepaid and other current assets when the amount of RINs earned and purchased is greater than the RINs liability. In addition, the Company is subject to obligations to comply with federal and state legislative and regulatory measures, including regulations in the state of California pursuant to Assembly Bill 32 (“AB 32”), to address environmental compliance and greenhouse gas and other emissions. These requirements include incremental costs to operate and maintain our facilities as well as to implement and manage new emission controls and programs. Renewable energy credit and emissions obligations fluctuate with the volume of applicable product sales and timing of credit purchases. TheFrom time to time, the Company enters into forward purchase commitments in order to acquire its renewable energy and emissions credits at fixed prices. As of SeptemberJune 30, 2022,2023, the Company had entered into approximately $852.4$501.2 million of such forward purchase commitments with respect to its total accrued renewable energy and emissions obligations. Our RIN obligations will be settled in accordance with established regulatory deadlines. The Company’s AB 32 liability is part of aan ongoing triennial period program which will be settled through 2024.
(b) The Company hashad the obligation to repurchase the J. Aron Products that arewere held in its Storage Tanks in accordance with the Third Inventory Intermediation Agreement with J. Aron.Agreement. As of SeptemberJune 30, 20222023 and December 31, 2021,2022, a liability iswas recognized forbased on the repurchase obligation under the Third Inventory Intermediation Agreement and is recorded at market price for the J. Aron owned inventory held in the Company’s Storage Tanks, with any change in the market price being recorded in Cost of products and other. As described in “Note 3 - Inventories”, the Company amended this agreement to allow for an early termination effective July 31, 2023.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
5. CREDIT FACILITIES AND DEBT
Debt outstanding consists of the following: | | (in millions) | (in millions) | | September 30, 2022 | | December 31, 2021 | (in millions) | | June 30, 2023 | | December 31, 2022 |
| 2025 Senior Secured Notes | | $ | — | | | $ | 1,250.0 | | |
| 2028 Senior Notes | 2028 Senior Notes | | 801.6 | | | 826.5 | | 2028 Senior Notes | | $ | 801.6 | | | $ | 801.6 | |
| 2025 Senior Notes | 2025 Senior Notes | | 664.5 | | | 669.5 | | 2025 Senior Notes | | 664.5 | | | 664.5 | |
| Revolving Credit Facility | Revolving Credit Facility | | — | | | 900.0 | | Revolving Credit Facility | | — | | | — | |
| | Catalyst financing arrangements | Catalyst financing arrangements | | 21.3 | | | 58.4 | | Catalyst financing arrangements | | 2.7 | | | 4.0 | |
| | 1,487.4 | | | 3,704.4 | | | 1,468.8 | | | 1,470.1 | |
| | Unamortized premium | Unamortized premium | | — | | | 0.5 | | Unamortized premium | | — | | | — | |
| Unamortized deferred financing costs | Unamortized deferred financing costs | | (39.7) | | | (31.6) | | Unamortized deferred financing costs | | (27.3) | | | (35.2) | |
| Long-term debt | Long-term debt | | $ | 1,447.7 | | | $ | 3,673.3 | | Long-term debt | | $ | 1,441.5 | | | $ | 1,434.9 | |
Revolving Credit Facility
On May 25, 2022, PBF Holding and certain of its wholly-owned subsidiaries, as borrowers or subsidiary guarantors, entered into an amendment of its existing asset-based revolving credit agreement (the “Revolving Credit Agreement”), among PBF Holding, Bank of America, National Association as administrative agent, and certain other lenders. Among other things, the Revolving Credit Agreement amended and extended PBF Holding’s asset-based revolving credit facility (the “Revolving Credit Facility”) through January 2025 and increased the maximum commitment to $4.3 billion through May 2023 (currently set to adjust to $2.75 billion in May 2023 through January 2025). The amendments also redefine certain components of the Borrowing Base (as defined in the Revolving Credit Agreement) to reflect the existence of two tranches, tranche A which is comprised of existing lenders who have not elected to extend and whose commitments retain the existing maturity date under the existing revolving credit agreement of May 2, 2023 (the “Tranche A Commitments”) and tranche B, which is comprised of existing and new lenders whose commitments have an extended maturity date of January 31, 2025 (the “Tranche B Commitments”). The Tranche A Commitments total $1.55 billion and the Tranche B Commitments total $2.75 billion. The amendments also include changes to incorporate the adoption of Secured Overnight Financing Rate (“SOFR”) as a replacement of LIBOR, changes to joint lead arrangers, bookrunners, syndication agents and other titles, and other changes related to the foregoing. In addition, an accordion feature allows for additional Tranche B Commitments of up to an additional $500.0 million plus an amount equal to the Tranche A Commitments for existing Tranche A lenders.
Borrowings under the Revolving Credit Facility bear interest at the Alternative Base Rate plus the Applicable Margin or at the Term SOFR Rate plus the Applicable Margin (all as defined in the Revolving Credit Agreement). The Applicable Margin ranges from 0.25% to 1.00% for Alternative Base Rate Loans and from 1.25% to 2.00% for Term SOFR Loans, in each case depending on the Company’s corporate credit rating. In addition, the LC Participation Fee ranges from 1.00% to 1.75% depending on the Company’s corporate credit rating and the Fronting Fee is capped at 0.25%.
The Revolving Credit Agreement contains customary covenants and restrictions on the activities of PBF Holding and its subsidiaries, including, but not limited to, limitations on incurring additional indebtedness, liens, negative pledges, guarantees, investments, loans, asset sales, mergers and acquisitions, prepayment of other debt, distributions, dividends and the repurchase of capital stock, transactions with affiliates and the ability of PBF Holding to change the nature of its business or its fiscal year; all as defined in the Revolving Credit Agreement.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
In addition, the Revolving Credit Agreement has a financial covenant which requires that if at any time Excess Availability, as defined in the Revolving Credit Agreement, is less than the greater of (i) 10% of the lesser of the then existing Borrowing Base and the then aggregate Revolving Commitments of the Lenders (the “Financial Covenant Testing Amount”), and (ii) $100.0 million, and until such time as Excess Availability is greater than the Financial Covenant Testing Amount and $100.0 million for a period of 12 or more consecutive days, PBF Holding will not permit the Consolidated Fixed Charge Coverage Ratio, as defined in the Revolving Credit Agreement and determined as of the last day of the most recently completed quarter, to be less than 1 to 1. As of SeptemberJune 30, 2022,2023, the Company is in compliance with all covenants, in the Revolving Credit Agreement, including financial covenants.covenants, in all its debt agreements.
PBF Holding’s obligations under the Revolving Credit Facility are (a) guaranteed by each of its domestic operating subsidiaries that are not Excluded Subsidiaries (as defined in the Revolving Credit Agreement) and (b) secured by a lien on (i) PBF LLC’s equity interest in PBF Holding and (ii) certain assets of PBF Holding and the subsidiary guarantors, including all deposit accounts (other than zero balance accounts, cash collateral accounts, trust accounts and/or payroll accounts, all of which are excluded from the definition of collateral), all accounts receivable, all hydrocarbon inventory (other than the J. Aron Products owned by J. Aron pursuant to the Third Inventory Intermediation Agreement) and to the extent evidencing, governing, securing or otherwise related to the foregoing, all general intangibles, chattel paper, instruments, documents, letter of credit rights and supporting obligations; and all products and proceeds of the foregoing.
Extinguishment of Debt
During the three and nine months ended September 30, 2022, the Company exercised its rights under the indenture governing the 9.25% senior secured notes due 2025 (the “2025 Senior Secured Notes”) to redeem all of the outstanding 2025 Senior Secured Notes at a price of 104.625% of the aggregate principal amount thereof plus accrued and unpaid interest. The aggregate redemption price for all 2025 Senior Secured Notes approximated $1.3 billion plus accrued and unpaid interest. The difference between the carrying value of the 2025 Senior Secured Notes on the date they were redeemed and the amount for which they were redeemed was $69.9 million and was recorded as a loss on extinguishment of debt in the Consolidated Statements of Operations.
During the nine months ended September 30, 2022, the Company made a number of open market repurchases of its 6.00% senior unsecured notes due 2028 (the “2028 Senior Notes”) and 7.25% senior unsecured notes due 2025 (the “2025 Senior Notes”) that resulted in the extinguishment of $24.9 million in principal of the 2028 Senior Notes and $5.0 million in principal of the 2025 Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, totaled $25.9 million and the Company recognized a $3.8 million gain on the extinguishment of debt during the nine months ended September 30, 2022.
During the three and nine months ended September 30, 2021, the Company made a number of open market repurchases of its 2028 Senior Notes and its 2025 Senior Notes that resulted in the extinguishment of $117.7 million in principal of the 2028 Senior Notes and $35.0 million in principal of the 2025 Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, totaled $90.9 million and the Company recognized a $60.3 million gain on the extinguishment of debt during the three and nine months ended September 30, 2021.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
6. RELATED PARTY TRANSACTIONS
Pending PBFX Merger
On July 27, 2022, PBF Energy and PBF LLC entered into a definitive agreement with PBFX (the “Merger Agreement”) pursuant to which PBF Energy and PBF LLC will acquire all of the publicly held common units in PBFX representing limited partner interests in the publicly-traded master limited partnership not already owned by certain wholly-owned subsidiaries of PBF Energy and its affiliates on the closing date of the transaction (the “Merger Transaction”).
The consideration to the PBFX common unitholders (other than PBF Energy and its affiliates) under the Merger Transaction consists of cash and PBF Energy Class A common stock. The Merger Agreement provides that, if completed, each outstanding PBFX Public Common Unit will have the right to receive (i) 0.27 shares of PBF Energy Class A common stock, par value $0.001 per share, (ii) $9.25 in cash, without interest, (iii) any dividends or other distributions to which the holder thereof becomes entitled to upon surrender of such outstanding common units held by an unaffiliated common unitholder in accordance with the Merger Agreement, and (iv) any cash in lieu of fractional shares of PBF Energy Class A common stock in accordance with the Merger Agreement. PBF Energy and PBF LLC, as the beneficial owners of 47.7% of PBFX’s outstanding common units, have committed to vote such units to approve the transaction.
The terms of the Merger Transaction were unanimously approved by the conflicts committee (the “Conflicts Committee”) of the Board of Directors (the “PBFX Board”) of PBFX’s general partner and by the PBFX Board based on the unanimous approval and recommendation of the Conflicts Committee, which is comprised entirely of independent directors. Upon closing, PBFX will become an indirect wholly-owned subsidiary of PBF Energy and PBF LLC.
The Merger Transaction is subject to customary closing conditions and the approval of the PBFX common unitholders (including PBF Energy). The transaction is expected to close in the fourth quarter of 2022, however there can be no assurance that the Merger Transaction will be consummated in the anticipated timeframe, on the contemplated terms or at all.
Transactions and Agreements with PBFX
The Company entered into agreements with PBFX that establish fees for certain general and administrative services, and operational and maintenance services provided by the Company to PBFX. In addition, the Company executed terminal, pipeline and storage services agreements with PBFX under which PBFX provides commercial transportation, terminaling, storage and pipeline services to the Company. These agreements with PBFX include:
Contribution Agreements
Immediately prior to the closing of certain contribution agreements, which PBF LLC entered into with PBFX (collectively referred to as the “Contribution Agreements”), the Company contributed certain assets to PBF LLC. PBF LLC in turn contributed those assets to PBFX pursuant to the Contribution Agreements. Certain proceeds received by PBF LLC from PBFX in accordance with the Contribution Agreements were subsequently contributed by PBF LLC to the Company.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
There were no agreements entered into during the three and six months ended June 30, 2023.Commercial Agreements
The Company has entered into long-term, fee-based commercial agreements with PBFX relating to assets associated with the Contribution Agreements, the majority of which include a minimum volume commitment (“MVC”) and are supported by contractual fee escalations for inflation adjustments and certain increases in operating costs. Under these agreements, PBFX provides various pipeline, rail and truck terminaling and storage services to the Company and the Company has committed to provide PBFX with minimum fees based on minimum monthly throughput volumes. The Company believes the terms and conditions under these agreements, as well as the Omnibus Agreement and the Services Agreement (each as defined below) with PBFX, are generally no less favorable to either party than those that could have been negotiated with unaffiliated parties with respect to similar services. There were no agreements entered into during the three and six months ended June 30, 2023.
Other Agreements
In addition to the commercial agreements described above, the Company has entered into an omnibus agreement with PBFX, PBF GP and PBF LLC, which has been amended and restated in connection with certain Contribution Agreements (as amended, the “Omnibus Agreement”). The Omnibus Agreement addresses the payment of an annual fee for the provision of various general and administrative services and reimbursement of salary and benefit costs for certain PBF Energy employees.
Additionally, the Company and certain of its subsidiaries have entered into an operation and management services and secondment agreement with PBFX (as amended, the “Services Agreement”), pursuant to which the Company and its subsidiaries provide PBFX with the personnel necessary for PBFX to perform its obligations under its commercial agreements. PBFX reimburses the Company for the use of such employees and the provision of certain infrastructure-related services to the extent applicable to its operations, including storm water discharge and waste water treatment, steam, potable water, access to certain roads and grounds, sanitary sewer access, electrical power, emergency response, filter press, fuel gas, API solids treatment, fire water and compressed air. The Services Agreement will terminate upon the termination of the Omnibus Agreement, provided that PBFX may terminate any service upon 30-days’ notice.
Refer to the Company’s 20212022 Annual Report on Form 10-K (“Note 1110 - Related Party Transactions” of the Notes to Consolidated Financial Statements) for a more complete description of the agreements with PBFX that were entered into prior to 2022.
The following table reflects activity during 2022 related to commercial agreements between PBF Holding and PBFX:
| | | | | | | | | | | | | | | | | |
Agreement | Initiation Date | Initial Term | Renewal | MVC | Force Majeure |
Transportation and Terminaling | | | | | |
Toledo Truck Unloading & Terminaling Agreement (a) | 4/1/2022 | 9 months | Evergreen | See note (b) | PBF Holding or PBFX can declare |
___________________
(a)This commercial agreement with PBFX is considered a lease.
(b)The MVC is 5,500 bpd through December 31, 2022. Effective January 1, 2023, the MVC will decrease to 1,000 bpd.2023.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Summary of Transactions with PBFX
A summary of the Company’s affiliate transactions with PBFX is as follows:
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| (in millions) | (in millions) | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | 2023 | | 2022 | | 2023 | | 2022 |
| Reimbursements under affiliate agreements: | Reimbursements under affiliate agreements: | | Reimbursements under affiliate agreements: | |
| Services Agreement | Services Agreement | $ | 2.2 | | | $ | 2.2 | | | $ | 6.5 | | | $ | 6.5 | | Services Agreement | $ | 2.1 | | | $ | 2.1 | | | $ | 4.3 | | | $ | 4.3 | |
| Omnibus Agreement | Omnibus Agreement | 2.1 | | | 1.8 | | | 6.2 | | | 5.5 | | Omnibus Agreement | 2.1 | | | 2.3 | | | 3.9 | | | 4.1 | |
| Total expenses under affiliate agreements | Total expenses under affiliate agreements | 77.4 | | | 75.5 | | | 233.0 | | | 226.5 | | Total expenses under affiliate agreements | 84.8 | | | 79.6 | | | 173.8 | | | 155.6 | |
Total reimbursements under the Omnibus Agreement are included in General and administrative expenses and reimbursements under the Services Agreement and expenses under affiliate agreements are included in Cost of products and other in the Company’s Condensed Consolidated Statements of Operations.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
7. COMMITMENTS AND CONTINGENCIES
In the ordinary conduct of the Company’s business, the Company is from time to time subject to lawsuits, investigations and claims, including class action proceedings, mass tort actions, tort actions, environmental claims and employee-related matters. The outcome of these matters cannot always be predicted accurately, but the Company accrues liabilities for these matters if the Company has determined that it is probable a loss has been incurred and the loss can be reasonably estimated. For such ongoing matters for which we have not recorded a liability but losses are reasonably possible, we are unable to estimate a range of possible losses at this time due to various reasons that may include but are not limited to, matters being in an early stage and not fully developed through pleadings, discovery or court proceedings, number of potential claimants being unknown or uncertainty regarding a number of different factors underlying the potential claims. However, the ultimate resolution of one or more of these contingencies could result in an adverse outcome that may have a material effect on our financial position, results of operations or cash flows.
Environmental Matters
The Company’s refineries, pipelines and related operations are subject to extensive and frequently changing federal, state and local laws and regulations, including, but not limited to, those relating to the discharge of materials into the environment or that otherwise relate to the protection of the environment (including in response to the potential impacts of climate change), waste management and the characteristics and the compositions of fuels. Compliance with existing and anticipated laws and regulations can increase the overall cost of operating the refineries, including remediation, operating costs and capital costs to construct, maintain and upgrade equipment and facilities.
These laws and permits raise potential exposure to future claims and lawsuits involving environmental and safety matters which could include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which the Company manufactured, handled, used, released or disposed of, transported, or that relate to pre-existing conditions for which the Company has assumed responsibility. The Company believes that its current operations are in compliance with existing environmental and safety requirements. However, there have been and will continue to be ongoing discussions about environmental and safety matters between the Company and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures. While it is often difficult to quantify future environmental or safety related expenditures, the Company anticipates that continuing capital investments and changes in operating procedures will be required for the foreseeable future to comply with existing and new requirements, as well as evolving interpretations and more strict enforcement of existing laws and regulations.
In connection with the acquisition of the Torrance refinery and related logistics assets, the Company assumed certain pre-existing environmental liabilities. The estimated costs related to these remediation obligations totaled $112.5$113.3 million as of SeptemberJune 30, 20222023 ($118.5117.0 million as of December 31, 2021)2022), and related primarily to remediation obligations to address existing soil and groundwater contamination and the related monitoring and clean-up activities. Costs related to these obligations are reassessed periodically or when changes to our remediation approach are identified. The current portion of the environmental liability is recorded in Accrued expenses and the non-current portion is recorded in Other long-term liabilities.
The aggregate environmental liability reflected in the Company’s Condensed Consolidated Balance Sheets was $151.7$154.6 million and $155.3$155.6 million at SeptemberJune 30, 20222023 and December 31, 2021,2022, respectively, of which $137.4$140.9 million and $141.0$141.5 million, respectively, were classified as Other long-term liabilities. These liabilities include remediation and monitoring costs expected to be incurred over an extended period of time. Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
Contingent Consideration
In connection with the acquisition of the Martinez refinery and related logistics assets, the sale and purchase agreement dated June 11, 2019 includesincluded an earn-out provision based on certain earnings thresholds of the Martinez refinery. Pursuant to the agreement, the Company will make payments to Equilon Enterprises LLC d/b/a Shell Oil Products US, based on future earnings at the Martinez refinery in excess of certain thresholds, as defined in the agreement, for a period of up to four years following the acquisition closing date (the “Martinez Contingent Consideration”). TheUpon acquisition of the refinery, the Company recorded the estimated acquisition date fair value of the earn-out provision as contingent consideration of $77.3 million within “Other long-term liabilities” within the Company’s Condensed Consolidated Balance Sheets.Sheet. Subsequent changes in the fair value of the Martinez Contingent Consideration are recorded in the Condensed Consolidated Statements of Operations. The fair value of the Martinez Contingent Consideration was estimated to be $160.1$29.4 million as of SeptemberJune 30, 2022 (of which $93.9 million2023 and is included within Accrued expenses) and $29.4expenses within the Company’s Condensed Consolidated Balance Sheet. The fair value of the Martinez Contingent Consideration was estimated to be $147.3 million as of December 31, 2021 (all of2022 (of which approximately $80.0 million was included within Other long-term liabilities) on the Company’s Condensed Consolidated Balance Sheets.Accrued expenses and paid in April 2023).
8. EMPLOYEE BENEFIT PLANS
The components of net periodic benefit cost related to the Company’s defined benefit plans consisted of the following:
| | (in millions) | Three Months Ended September 30, | | Nine Months Ended September 30, | |
| (In millions) | | (In millions) | Three Months Ended June 30, | | Six Months Ended June 30, |
| Pension Benefits | Pension Benefits | 2022 | | 2021 | | 2022 | | 2021 | Pension Benefits | 2023 | | 2022 | | 2023 | | 2022 |
| Components of net periodic benefit cost: | Components of net periodic benefit cost: | | Components of net periodic benefit cost: | |
| Service cost | Service cost | $ | 13.9 | | | $ | 14.4 | | | $ | 41.7 | | | $ | 43.1 | | Service cost | $ | 11.9 | | | $ | 13.9 | | | $ | 24.0 | | | $ | 27.8 | |
| Interest cost | Interest cost | 1.8 | | | 1.3 | | | 5.8 | | | 4.0 | | Interest cost | 4.6 | | | 1.9 | | | 8.9 | | | 3.9 | |
| Expected return on plan assets | Expected return on plan assets | (4.3) | | | (3.6) | | | (13.1) | | | (10.7) | | Expected return on plan assets | (4.8) | | | (4.3) | | | (9.6) | | | (8.7) | |
| Amortization of prior service cost and actuarial loss | 0.1 | | | 0.1 | | | 0.1 | | | 0.1 | | |
| | Net periodic benefit cost | Net periodic benefit cost | $ | 11.5 | | | $ | 12.2 | | | $ | 34.5 | | | $ | 36.5 | | Net periodic benefit cost | $ | 11.7 | | | $ | 11.5 | | | $ | 23.3 | | | $ | 23.0 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| (in millions) | Three Months Ended September 30, | | Nine Months Ended September 30, |
| Post-Retirement Medical Plan | 2022 | | 2021 | | 2022 | | 2021 |
| Components of net periodic benefit cost: | | | | | | | |
| Service cost | $ | 0.2 | | | $ | 0.3 | | | $ | 0.6 | | | $ | 0.8 | |
| Interest cost | — | | | 0.1 | | | 0.3 | | | 0.2 | |
| Amortization of prior service cost and actuarial loss | 0.2 | | | 0.1 | | | 0.3 | | | 0.5 | |
| Net periodic benefit cost | $ | 0.4 | | | $ | 0.5 | | | $ | 1.2 | | | $ | 1.5 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| (In millions) | Three Months Ended June 30, | | Six Months Ended June 30, |
| Post-Retirement Medical Plan | 2023 | | 2022 | | 2023 | | 2022 |
| Components of net periodic benefit cost: | | | | | | | |
| Service cost | $ | 0.1 | | | $ | 0.2 | | | $ | 0.3 | | | $ | 0.4 | |
| Interest cost | 0.1 | | | 0.2 | | | 0.3 | | | 0.3 | |
| Amortization of prior service cost and actuarial loss | — | | | — | | | — | | | 0.1 | |
| Net periodic benefit cost | $ | 0.2 | | | $ | 0.4 | | | $ | 0.6 | | | $ | 0.8 | |
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
9. REVENUES
The following table provides information relating to the Company’s revenues from external customers for each product or group of similar products for the periods presented:
| | | Three Months Ended September 30, | | Three Months Ended June 30, |
| (in millions) | (in millions) | 2022 | | 2021 | (in millions) | 2023 | | 2022 |
| Gasoline and distillates | Gasoline and distillates | $ | 11,244.4 | | | $ | 6,143.4 | | Gasoline and distillates | $ | 8,142.1 | | | $ | 12,520.9 | |
| Asphalt and blackoils | Asphalt and blackoils | 603.9 | | | 329.2 | | Asphalt and blackoils | 385.0 | | | 667.2 | |
| Feedstocks and other | Feedstocks and other | 554.3 | | | 380.3 | | Feedstocks and other | 349.8 | | | 451.9 | |
| Chemicals | Chemicals | 246.4 | | | 240.7 | | Chemicals | 174.2 | | | 291.2 | |
| Lubricants | Lubricants | 103.3 | | | 79.7 | | Lubricants | 97.3 | | | 132.8 | |
| Total Revenues | Total Revenues | $ | 12,752.3 | | | $ | 7,173.3 | | Total Revenues | $ | 9,148.4 | | | $ | 14,064.0 | |
| | | Nine Months Ended September 30, | | Six Months Ended June 30, |
| (in millions) | (in millions) | 2022 | | 2021 | (in millions) | 2023 | | 2022 |
| Gasoline and distillates | Gasoline and distillates | $ | 31,803.0 | | | $ | 16,364.1 | | Gasoline and distillates | $ | 16,374.7 | | | $ | 20,558.6 | |
| Asphalt and blackoils | Asphalt and blackoils | 1,730.0 | | | 843.0 | | Asphalt and blackoils | 788.2 | | | 1,126.1 | |
| Feedstocks and other | Feedstocks and other | 1,341.1 | | | 883.2 | | Feedstocks and other | 767.6 | | | 786.8 | |
| Chemicals | Chemicals | 744.6 | | | 665.8 | | Chemicals | 314.4 | | | 498.2 | |
| Lubricants | Lubricants | 325.8 | | | 213.6 | | Lubricants | 189.0 | | | 222.5 | |
| Total Revenues | Total Revenues | $ | 35,944.5 | | | $ | 18,969.7 | | Total Revenues | $ | 18,433.9 | | | $ | 23,192.2 | |
The Company’s revenues are generated from the sale of refined products. These revenues are largely based on the current spot (market) prices of the products sold, which represent consideration specifically allocable to the products being sold on a given day, and the Company recognizes those revenues upon delivery and transfer of title to the products to our customers. The time at which delivery and transfer of title occurs is the point when the Company’s control of the products is transferred to the Company’s customers and when its performance obligation to its customers is fulfilled. Delivery and transfer of title are specifically agreed to between the Company and customers within the contracts. The Company also has contracts which contain fixed pricing, tiered pricing, minimum volume features with makeup periods, or other factors that have not materially been affected by Accounting Standards Codification (“ASC”) 606, Revenue from Contracts with Customers.
Deferred Revenue
The Company records deferred revenue when cash payments are received or are due in advance of performance, including amounts which are refundable. Deferred revenue was $71.9$74.8 million and $40.3$37.5 million as of SeptemberJune 30, 20222023 and December 31, 2021,2022, respectively. Fluctuations in the deferred revenue balance are primarily driven by the timing and extent of cash payments received or due in advance of satisfying the Company’s performance obligations.
The Company’s payment terms vary by type and location of customers and the products offered. The period between invoicing and when payment is due is not significant (i.e. generally within two months). For certain products or services and customer types, the Company requires payment before the products or services are delivered to the customer.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
10. INCOME TAXES
PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes. Accordingly, there is generally no benefit or expense for federal or state income tax in the PBF Holding financial statements apart from the income tax attributable to the two subsidiaries acquired in connection with the acquisition of Chalmette Refining and the Company’s wholly-owned Canadian subsidiary, PBF Energy Limited, which are treated as C-Corporations for income tax purposes, with the tax provision calculated based on the effective tax rate for the periods presented.
The reported income tax provision in the PBF Holding Condensed Consolidated Statements of Operations consists of the following:
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| (in millions) | (in millions) | | 2022 | | 2021 | | 2022 | | 2021 | (in millions) | | 2023 | | 2022 | | 2023 | | 2022 |
| Current income tax expense (benefit) | Current income tax expense (benefit) | | $ | 0.4 | | | $ | (0.2) | | | $ | 0.4 | | | $ | (1.3) | | Current income tax expense (benefit) | | $ | 0.2 | | | $ | — | | | $ | (0.7) | | | $ | — | |
| Deferred income tax expense (benefit) | | 10.0 | | | (1.8) | | | 0.7 | | | (15.6) | | |
| Total income tax expense (benefit) | | $ | 10.4 | | | $ | (2.0) | | | $ | 1.1 | | | $ | (16.9) | | |
| Deferred income tax (benefit) expense | | Deferred income tax (benefit) expense | | (0.2) | | | (1.2) | | | 0.1 | | | (9.3) | |
| Total income tax benefit | | Total income tax benefit | | $ | — | | | $ | (1.2) | | | $ | (0.6) | | | $ | (9.3) | |
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
11. FAIR VALUE MEASUREMENTS
The tables below present information about the Company’s financial assets and liabilities measured and recorded at fair value on a recurring basis and indicate the fair value hierarchy of the inputs utilized to determine the fair values as of SeptemberJune 30, 20222023 and December 31, 2021.2022.
The Company has elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty; however, fair value amounts by hierarchy level are presented on a gross basis in the tables below. The Company has posted cash margin with various counterparties to support hedging and trading activities. The cash margin posted is required by counterparties as collateral deposits and cannot be offset against the fair value of open contracts except in the event of default. The Company has no derivative contracts that are subject to master netting arrangements that are reflected gross on the Condensed Consolidated Balance Sheets.
| | | As of September 30, 2022 | | As of June 30, 2023 |
| | Fair Value Hierarchy | | Total Gross Fair Value | | Effect of Counter-party Netting | | Net Carrying Value on Balance Sheet | | Fair Value Hierarchy | | Total Gross Fair Value | | Effect of Counter-party Netting | | Net Carrying Value on Balance Sheet |
| (in millions) | (in millions) | Level 1 | | Level 2 | | Level 3 | | (in millions) | Level 1 | | Level 2 | | Level 3 | |
| Assets: | Assets: | | Assets: | |
| Money market funds | Money market funds | $ | 75.2 | | | $ | — | | | $ | — | | | $ | 75.2 | | | N/A | | $ | 75.2 | | Money market funds | $ | 125.4 | | | $ | — | | | $ | — | | | $ | 125.4 | | | N/A | | $ | 125.4 | |
| | Commodity contracts | Commodity contracts | 354.2 | | | 32.6 | | | — | | | 386.8 | | | (366.6) | | | 20.2 | | Commodity contracts | 20.3 | | | 33.8 | | | 11.9 | | | 66.0 | | | (49.4) | | | 16.6 | |
| Derivatives included with inventory intermediation agreement obligations | — | | | 40.9 | | | — | | | 40.9 | | | — | | | 40.9 | | |
| Derivatives included within inventory intermediation agreement obligations | | Derivatives included within inventory intermediation agreement obligations | — | | | 16.6 | | | — | | | 16.6 | | | — | | | 16.6 | |
| | Liabilities: | Liabilities: | | Liabilities: | |
| Commodity contracts | Commodity contracts | 360.3 | | | 6.3 | | | — | | | 366.6 | | | (366.6) | | | — | | Commodity contracts | 13.4 | | | 36.0 | | | — | | | 49.4 | | | (49.4) | | | — | |
| Catalyst obligations | Catalyst obligations | — | | | 21.3 | | | — | | | 21.3 | | | — | | | 21.3 | | Catalyst obligations | — | | | 2.7 | | | — | | | 2.7 | | | — | | | 2.7 | |
| Renewable energy credit and emissions obligations | Renewable energy credit and emissions obligations | — | | | 1,233.8 | | | — | | | 1,233.8 | | | — | | | 1,233.8 | | Renewable energy credit and emissions obligations | — | | | 792.3 | | | — | | | 792.3 | | | — | | | 792.3 | |
| Contingent consideration obligation | Contingent consideration obligation | — | | | — | | | 160.1 | | | 160.1 | | | — | | | 160.1 | | Contingent consideration obligation | — | | | — | | | 29.4 | | | 29.4 | | | — | | | 29.4 | |
|
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
| | | As of December 31, 2021 | | As of December 31, 2022 |
| | Fair Value Hierarchy | | Total Gross Fair Value | | Effect of Counter-party Netting | | Net Carrying Value on Balance Sheet | | Fair Value Hierarchy | | Total Gross Fair Value | | Effect of Counter-party Netting | | Net Carrying Value on Balance Sheet |
| (in millions) | (in millions) | Level 1 | | Level 2 | | Level 3 | | (in millions) | Level 1 | | Level 2 | | Level 3 | |
| Assets: | Assets: | | Assets: | |
| Money market funds | Money market funds | $ | 260.9 | | | $ | — | | | $ | — | | | $ | 260.9 | | | N/A | | $ | 260.9 | | Money market funds | $ | 106.5 | | | $ | — | | | $ | — | | | $ | 106.5 | | | N/A | | $ | 106.5 | |
| | Commodity contracts | Commodity contracts | 71.5 | | | — | | | — | | | 71.5 | | | (71.5) | | | — | | Commodity contracts | 33.8 | | | 15.7 | | | — | | | 49.5 | | | (35.6) | | | 13.9 | |
| Derivatives included with inventory intermediation agreement obligations | — | | | 19.7 | | | — | | | 19.7 | | | — | | | 19.7 | | |
| Derivatives included within inventory intermediation agreement obligations | | Derivatives included within inventory intermediation agreement obligations | — | | | 25.1 | | | — | | | 25.1 | | | — | | | 25.1 | |
| | Liabilities: | Liabilities: | | Liabilities: | |
| Commodity contracts | Commodity contracts | 79.7 | | | 3.8 | | | — | | | 83.5 | | | (71.5) | | | 12.0 | | Commodity contracts | 20.6 | | | 11.8 | | | 3.2 | | | 35.6 | | | (35.6) | | | — | |
| Catalyst obligations | Catalyst obligations | — | | | 58.4 | | | — | | | 58.4 | | | — | | | 58.4 | | Catalyst obligations | — | | | 4.0 | | | — | | | 4.0 | | | — | | | 4.0 | |
| Renewable energy credit and emissions obligations | Renewable energy credit and emissions obligations | — | | | 953.9 | | | — | | | 953.9 | | | — | | | 953.9 | | Renewable energy credit and emissions obligations | — | | | 1,361.1 | | | — | | | 1,361.1 | | | — | | | 1,361.1 | |
| Contingent consideration obligation | Contingent consideration obligation | — | | | — | | | 29.4 | | | 29.4 | | | — | | | 29.4 | | Contingent consideration obligation | — | | | — | | | 147.3 | | | 147.3 | | | — | | | 147.3 | |
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The valuation methods used to measure financial instruments at fair value are as follows:
•Money market funds categorized in Level 1 of the fair value hierarchy are measured at fair value based on quoted market prices and included within Cash and cash equivalents.
•The commodity contracts categorized in Level 1 of the fair value hierarchy are measured at fair value based on quoted prices in an active market. The commodity contracts categorized in Level 2 of the fair value hierarchy are measured at fair value using a market approach based upon future commodity prices for similar instruments quoted in active markets.
•The derivatives included with inventory intermediation agreement obligations and the catalyst obligations are categorized in Level 2 of the fair value hierarchy and are measured at fair value using a market approach based upon commodity prices for similar instruments quoted in active markets.
•Renewable energy credit and emissions obligations primarily represent ourthe Company’s liability for the purchase of (i) biofuel credits (primarily RINs in the U.S.) needed to satisfy ourits obligation to blend biofuels into the products we producethe Company produces and (ii) emission credits under the AB 32 and similar programs (collectively, the cap-and-trade systems). To the degree we arethe Company is unable to blend biofuels (such as ethanol and biodiesel) at percentages required under the biofuel programs, weit must purchase biofuel credits to comply with these programs. Under the cap-and-trade systems, weit must purchase emission credits to comply with these systems. The liability for environmental credits is in part based on ourthe Company’s deficit for such credits as of the balance sheet date, if any, after considering any credits acquired, or under contract, and is equal to the product of the credits deficit and the market price of these credits as of the balance sheet date. To the extent that the Company has a better estimate of the cost at which it settle its obligation, such as agreements to purchase RINs at prices other than the current spot price, the Company considers those costs in valuing the remaining obligation. The environmental credit obligations are categorized in Level 2 of the fair value hierarchy and arethe Company measured at fair value using a market approach based on quoted prices from an independent pricing service.
•When applicable, commodity contracts categorized in Level 3 of the fair value hierarchy consist of commodity price swap contracts that relate to forecasted purchases of crude oil for which quoted forward market prices are not readily available due to market illiquidity. The forward prices used to value these swaps are derived using broker quotes, prices from other third-party sources and other available market based data.
•The contingent consideration obligationsobligation at SeptemberJune 30, 20222023 and December 31, 2021 are2022 is categorized in Level 3 of the fair value hierarchy and areis estimated using discounted cash flow models based on management’s estimate of the future cash flows related to the earn-out periods.
Non-qualified pension plan assets are measured at fair value using a market approach based on published net asset values of mutual funds as a practical expedient. As of SeptemberJune 30, 20222023 and December 31, 2021, $18.42022, $18.8 million and $20.7$18.6 million, respectively, were included within Deferred charges and other assets, net for these non-qualified pension plan assets.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The table below summarizes the changes in fair value measurements categorized in Level 3 of the fair value hierarchy, which primarily includes the change in estimated future earnings related to the Martinez Contingent Consideration:
| | | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| (in millions) | 2022 | | 2021 | | 2022 | 2021 | |
| (In millions) | | (In millions) | 2023 | | 2022 | | 2023 | 2022 |
| Balance at beginning of period | Balance at beginning of period | $ | 157.1 | | | $ | 24.3 | | | $ | 29.4 | | $ | — | | Balance at beginning of period | $ | 123.4 | | | $ | 79.5 | | | $ | 150.5 | | $ | 29.4 | |
| Additions | Additions | — | | | — | | | — | | — | | Additions | — | | | — | | | — | | — | |
| | Settlements | Settlements | — | | | — | | | — | | — | | Settlements | (78.2) | | | — | | | (83.6) | | — | |
| Unrealized loss (gain) included in earnings | 3.0 | | | (0.7) | | | 130.7 | | 23.6 | | |
| Unrealized (gain) loss included in earnings | | Unrealized (gain) loss included in earnings | (27.7) | | | 77.6 | | | (49.4) | | 127.7 | |
| | Balance at end of period | Balance at end of period | $ | 160.1 | | | $ | 23.6 | | | $ | 160.1 | | $ | 23.6 | | Balance at end of period | $ | 17.5 | | | $ | 157.1 | | | $ | 17.5 | | $ | 157.1 | |
There were no transfers between levels during the three and ninesix months ended SeptemberJune 30, 20222023 or the three and ninesix months ended SeptemberJune 30, 2021.2022.
Fair value of debt
The table below summarizes the carrying value and fair value of debt as of SeptemberJune 30, 20222023 and December 31, 2021.2022.
| | | September 30, 2022 | | December 31, 2021 | | June 30, 2023 | | December 31, 2022 |
| (in millions) | Carrying
value | | Fair
value | | Carrying
value | | Fair
value | |
| 2025 Senior Secured Notes (a) | $ | — | | | $ | — | | | $ | 1,250.0 | | | $ | 1,192.7 | | |
| (In millions) | | (In millions) | Carrying
value | | Fair
value | | Carrying
value | | Fair
value |
| 2028 Senior Notes (a) | 2028 Senior Notes (a) | 801.6 | | | 686.4 | | | 826.5 | | | 520.9 | | 2028 Senior Notes (a) | $ | 801.6 | | | $ | 747.9 | | | $ | 801.6 | | | $ | 703.7 | |
| 2025 Senior Notes (a) | 2025 Senior Notes (a) | 664.5 | | | 632.4 | | | 669.5 | | | 475.9 | | 2025 Senior Notes (a) | 664.5 | | | 664.6 | | | 664.5 | | | 656.0 | |
| | Revolving Credit Facility (b) | — | | | — | | | 900.0 | | | 900.0 | | |
| | Catalyst financing arrangements (c) | 21.3 | | | 21.3 | | | 58.4 | | | 58.4 | | |
| | Catalyst financing arrangements (b) | | Catalyst financing arrangements (b) | 2.7 | | | 2.7 | | | 4.0 | | | 4.0 | |
| | 1,487.4 | | | 1,340.1 | | | 3,704.4 | | | 3,147.9 | | | 1,468.8 | | | 1,415.2 | | | 1,470.1 | | | 1,363.7 | |
| | Unamortized premium | Unamortized premium | — | | | n/a | | 0.5 | | | n/a | Unamortized premium | — | | | n/a | | — | | | n/a |
| Less - Unamortized deferred financing costs | Less - Unamortized deferred financing costs | (39.7) | | | n/a | | (31.6) | | | n/a | Less - Unamortized deferred financing costs | (27.3) | | | n/a | | (35.2) | | | n/a |
| Long-term debt | Long-term debt | $ | 1,447.7 | | | $ | 1,340.1 | | | $ | 3,673.3 | | | $ | 3,147.9 | | Long-term debt | $ | 1,441.5 | | | $ | 1,415.2 | | | $ | 1,434.9 | | | $ | 1,363.7 | |
(a)The estimated fair value, categorized as a Level 2 measurement, was calculated based on the present value of future expected payments utilizing implied current market interest rates based on quoted prices of the outstanding senior notes.
(b)The estimated fair value approximates carrying value, categorized as a Level 2 measurement, as these borrowings bear interest based upon short-term floating market interest rates.
(c)Catalyst financing arrangements are valued using a market approach based upon commodity prices for similar instruments quoted in active markets and are categorized as a Level 2 measurement. The Company has elected the fair value option for accounting for its catalyst repurchase obligations as the Company’s liability is directly impacted by the change in fair value of the underlying catalyst.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
12. DERIVATIVES
The Company uses derivative instruments to mitigate certain exposures to commodity price risk. The Company entered into the Third Inventory Intermediation Agreement that contain purchase obligations for certain volumes of crude oil, intermediates and refined products. The purchase obligations related to crude oil, intermediates and refined products under these agreements are derivative instruments that have been designated as fair value hedges in order to hedge the commodity price volatility of certain refinery inventory. The fair value of these purchase obligation derivatives is based on market prices of the underlying crude oil, intermediates and refined products. The level of activity for these derivatives is based on the level of operating inventories.
As of SeptemberJune 30, 20222023 and December 31, 2021,2022, there were 2,022,8731,896,752 and 2,081,7831,945,994 barrels of crude oil and feedstocks outstanding under these derivative instruments designated as fair value hedges, respectively. As of SeptemberJune 30, 2022,2023, there were 1,016,8841,360,170 barrels of intermediates and refined products (2,070,550(780,734 barrels at December 31, 2021)2022) outstanding under these derivative instruments designated as fair value hedges. These volumes represent the notional value of the contract.
The Company also enters into economic hedges primarily consisting of commodity derivative contracts that are not designated as hedges and are used to manage price volatility in certain crude oil and feedstock inventories as well as crude oil, feedstock, and refined product sales or purchases. The objective in entering into economic hedges is consistent with the objectives discussed above for fair value hedges. As of SeptemberJune 30, 2022,2023, there were 59,925,00017,689,000 barrels of crude oil and 10,056,00011,686,400 barrels of refined products (36,246,000(17,890,000 and 5,819,000,12,175,200, respectively, as of December 31, 2021)2022), outstanding under short and long term commodity derivative contracts not designated as hedges representing the notional value of the contracts.
The Company also uses derivative instruments to mitigate the risk associated with the price of credits needed to comply with various governmental and regulatory environmental compliance programs. For such contracts that represent derivatives, the Company elects the normal purchase normal sale exception under ASC 815, Derivatives and Hedging, and therefore does not record them at fair value.
The following tables provide information regarding the fair values of derivative instruments as of SeptemberJune 30, 20222023 and December 31, 2021,2022, and the line items in the Condensed Consolidated Balance Sheets in which fair values are reflected.
| | | | | | | | |
| Description |
Balance Sheet Location | Fair Value
Asset/(Liability) |
| | (in millions) |
| Derivatives designated as hedging instruments: | | |
SeptemberJune 30, 2023: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Accrued expenses | $ | 16.6 | |
| December 31, 2022: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Accrued expenses | $ | 40.9 | |
December 31, 2021: | | |
| | |
Derivatives included within the inventory intermediation agreement obligations | Accrued expenses | $ | 19.725.1 | |
| | |
| Derivatives not designated as hedging instruments: | | |
SeptemberJune 30, 2023: | | |
| Commodity contracts | Accounts receivable | $ | 16.6 | |
| | |
| December 31, 2022: | | |
| Commodity contracts | Accounts receivable | $ | 20.2 | |
| | |
December 31, 2021: | | |
Commodity contracts | Accounts receivable | $ | (12.0)13.9 | |
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
The following table provides information regarding gains or losses recognized in income on derivative instruments and the line items in the Condensed Consolidated Statements of Operations in which such gains and losses are reflected.
| | | | | | | | |
| Description | Location of Gain or (Loss) Recognized in Income on Derivatives | Gain or (Loss)
Recognized in
Income on Derivatives |
| | (in millions) |
| Derivatives designated as hedging instruments: | | |
For the three months ended SeptemberJune 30, 2023: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Cost of products and other | $ | (12.7) | |
| For the three months ended June 30, 2022: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Cost of products and other | $ | 17.7 (37.3) | |
For the threesix months ended SeptemberJune 30, 2021:2023: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Cost of products and other | $ | (3.8)(8.5) | |
For the ninesix months ended SeptemberJune 30, 2022: | | |
| | |
| Derivatives included within the inventory intermediation agreement obligations | Cost of products and other | $ | 21.1 | |
For the nine months ended September 30, 2021: | | |
| | |
Derivatives included within the inventory intermediation agreement obligations | Cost of products and other | $ | (46.0)3.4 | |
| | |
| Derivatives not designated as hedging instruments: | | |
For the three months ended SeptemberJune 30, 2023: | | |
| Commodity contracts | Cost of products and other | $ | 23.3 | |
| For the three months ended June 30, 2022: | | |
| Commodity contracts | Cost of products and other | $ | 28.6 (25.2) | |
For the threesix months ended SeptemberJune 30, 2021:2023: | | |
| Commodity contracts | Cost of products and other | $ | (33.2)38.1 | |
For the ninesix months ended SeptemberJune 30, 2022: | | |
| Commodity contracts | Cost of products and other | $ | (23.5) | |
For the nine months ended September 30, 2021: | | |
Commodity contracts | Cost of products and other | $ | (67.7)(52.1) | |
| | |
| Hedged items designated in fair value hedges: | | |
For the three months ended SeptemberJune 30, 2023: | | |
| | |
| Crude oil, intermediate and refined product inventory | Cost of products and other | $ | 12.7 | |
| For the three months ended June 30, 2022: | | |
| | |
| Crude oil, intermediate and refined product inventory | Cost of products and other | $ | (17.7)37.3 | |
For the threesix months ended SeptemberJune 30, 2021:2023: | | |
| | |
| Crude oil, intermediate and refined product inventory | Cost of products and other | $ | 3.88.5 | |
For the ninesix months ended SeptemberJune 30, 2022: | | |
| | |
| Crude oil, intermediate and refined product inventory | Cost of products and other | $ | (21.1) | |
For the nine months ended September 30, 2021: | | |
| | |
Crude oil, intermediate and refined product inventory | Cost of products and other | $ | 46.0 (3.4) | |
The Company had no ineffectiveness related to the fair value hedges for the three and ninesix months ended SeptemberJune 30, 20222023 or the three and ninesix months ended SeptemberJune 30, 2021.2022.
PBF HOLDING COMPANY LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
13. SUBSEQUENT EVENTS
Dividend Declared
On October 27, 2022,August 3, 2023, PBF Energy, PBF Holding’s indirect parent, announced a dividend of $0.20 per share on its outstanding Class A common stock. The dividend is payable on November 29, 2022August 31, 2023 to PBF Energy Class A common stockholders of record at the close of business on November 14, 2022.August 17, 2023.
Early Termination of the Inventory Intermediation Agreement
On July 31, 2023, in conjunction with the early termination of the Third Inventory Intermediation Agreement, the Company made a provisional payment of $268.0 million for the inventory previously held by J. Aron and the related costs associated with exiting the agreement.
ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with the audited financial statements of PBF Holding included in the Annual Report on Form 10-K for the year ended December 31, 20212022 and the unaudited financial statements and related notes included in this report. The following discussion contains “forward-looking statements” that reflect our future plans, estimates, beliefs and expected performance. Our actual results may differ materially from those currently anticipated and expressed in such forward-looking statements as a result of a number of factors. We caution that assumptions, expectations, projections, intentions or beliefs about future events may, and often do, vary from actual results and the differences can be material. Please see “Cautionary Note Regarding Forward-Looking Statements.”
Unless the context indicates otherwise, the terms “we,” “us,” and “our” refer to PBF Holding and its consolidated subsidiaries.
Overview
We are one of the largest independent petroleum refiners and suppliers of unbranded transportation fuels, heating oil, petrochemical feedstocks, lubricants and other petroleum products in the United States. We sell our products throughout the Northeast, Midwest, Gulf Coast and West Coast of the United States, as well as in other regions of the United States, Canada and Mexico and are able to ship products to other international destinations. As of September 30, 2022, weWe own and operate six domestic oil refineries and related assets. Based on the current configuration ourOur refineries have a combined processing capacity, known as throughput, of approximately 1,000,000 barrels per day (“bpd”), and a weighted-average Nelson Complexity Index of 13.212.7 based on current operating conditions. The complexity and throughput capacity of our refineries are subject to change dependent upon configuration changes we make to respond to market conditions, as well as a result of investments made to improve our facilities and maintain compliance with environmental and governmental regulations. Our six oil refineries are aggregated into one reportable segment.
Our six refineries are located in Delaware City, Delaware, Paulsboro, New Jersey, Toledo, Ohio, Chalmette, Louisiana, Torrance, California and Martinez, California. In 2020, we reconfigured our Delaware City and Paulsboro refineries (the “East Coast Refining Reconfiguration”), temporarily idling certain of our major processing units at the Paulsboro refinery, in order to operate the two refineries as one functional unit that we refer to as the “East Coast Refining System”. Each refinery is briefly described in the table below:
| | | | | | | | | | | | | | | | | | | | |
| Refinery | Region | Nelson Complexity Index(1) | Throughput Capacity (in bpd)(1) | PADD | Crude Processed (2) | Source (2) |
| Delaware City | East Coast | 13.6 | 180,000 | 1 | light sweet through heavy sour | water, rail |
| Paulsboro | East Coast | 8.8(3) | 155,000(3) | 1 | light sweet through heavy sour | water |
| Toledo | Mid-Continent | 11.0 | 180,000 | 2 | light sweet | pipeline, truck, rail |
| Chalmette | Gulf Coast | 13.0 | 185,000 | 3 | light sweet through heavy sour | water, pipeline |
| Torrance | West Coast | 13.8 | 166,000 | 5 | medium and heavy | pipeline, water, truck |
| Martinez | West Coast | 16.1 | 157,000 | 5 | medium and heavy | pipeline and water |
| | | | | | | | | | | | | | | | | | | | |
| Refinery | Region | Nelson Complexity Index(1) | Throughput Capacity (in bpd)(1) | PADD | Crude Processed (2) | Source (2) |
| Delaware City | East Coast | 13.6 | 180,000 | 1 | light sweet through heavy sour | water, rail |
| Paulsboro | East Coast | 10.4(3) | 105,000(3) | 1 | light sweet through heavy sour | water |
| Toledo | Mid-Continent | 11.0 | 180,000 | 2 | light sweet | pipeline, truck, rail |
| Chalmette | Gulf Coast | 13.0 | 185,000 | 3 | light sweet through heavy sour | water, pipeline |
| Torrance | West Coast | 13.8 | 166,000 | 5 | medium and heavy | pipeline, water, truck |
| Martinez | West Coast | 16.1 | 157,000 | 5 | medium and heavy | pipeline and water |
________
(1) Reflects operating conditions at each refinery as of the date of this filing. Changes in complexity and throughput capacity reflect the result of current market conditions, such as our East Coast Refining Reconfiguration, in addition to investments made to improve our facilities and maintain compliance with environmental and governmental regulations. Configurations at each of our refineries are evaluated periodically and updated accordingly.
(2) Reflects the typical crude and feedstocks and related sources utilized under normal operating conditions and prevailing market environments.
(3) Under normal operating conditions and prevailing market environments, our Nelson Complexity Index and throughput capacity for the Paulsboro refinery would be 13.1 and 180,000, respectively. As a result of the reconfiguration of our East Coast Refining Reconfiguration,refineries in 2020, and subsequent restart of several idled processing units at the Paulsboro refinery in 2022, our Nelson Complexity Index and throughput capacity were reduced.adjusted.
We are a wholly-owned subsidiary of PBF LLC and an indirect subsidiary of PBF Energy. PBF Finance is a wholly-owned subsidiary of PBF Holding. We are the parent company for PBF LLC’s refinery operating subsidiaries.
Business Developments
Recent significant business developments affecting us are discussed below.
PendingPBF GP serves as the general partner of PBFX. PBFX Merger
On July 27, 2022,is an affiliate of ours. PBFX, an indirect wholly-owned subsidiary of PBF Energy and PBF LLC, entered intoowns or leases, operates, develops and acquires crude oil and refined products terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storage and transferring of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for PBF Energy in support of its refineries, as well as for third-party customers. The majority of PBFX’s revenues are derived from long-term, fee-based commercial agreements with us, which include minimum volume commitments, for receiving, handling, storing and transferring crude oil, refined products, and natural gas. PBF Energy also has agreements with PBFX that establish fees for certain general and administrative services and operational and maintenance services provided by us to PBFX.
On November 30, 2022, PBF Energy, PBF LLC, PBFX Holdings Inc., a Delaware corporation and wholly-owned subsidiary of PBF LLC, Riverlands Merger Sub LLC, a Delaware limited liability company and wholly owned subsidiary of PBF LLC, PBFX, and PBF GP closed on a definitive agreement with PBFX (the “Merger Agreement”) pursuant to which PBF Energy and PBF LLC will acquireacquired all of the publicly held common units in PBFX representing limited partner interests in the publicly-traded master limited partnershipliability project not already owned by certain wholly-owned subsidiaries of PBF Energy and its affiliates on the date of the transaction (the “Merger Transaction”).
The consideration Subsequent to the PBFX common unitholders (other than PBF Energy and its affiliates) underclosing on the Merger Transaction, consists of cash and PBF Energy Class A common stock. The Merger Agreement provides that, if completed, each outstanding PBFX Public Common Unit will have the right to receive (i) 0.27 shares of PBF Energy Class A common stock, par value $0.001 per share, (ii) $9.25 in cash, without interest, (iii) any dividends or other distributions to which the holder thereof becomes entitled to upon surrender of such outstanding common units held by an unaffiliated common unitholder in accordance with the Merger Agreement, and (iv) any cash in lieu of fractional shares of PBF Energy Class A common stock in accordance with the Merger Agreement. PBF Energy and PBF LLC, as the beneficial owners of 47.7% of PBFX’s outstanding common units, have committed to vote such units to approve the transaction.
The terms of the Merger Transaction were unanimously approved by the conflicts committee (the “Conflicts Committee”) of the Board of Directors (the “PBFX Board”) of PBFX’s general partner and by the PBFX Board based on the unanimous approval and recommendation of the Conflicts Committee, which is comprised entirely of independent directors. Upon closing, PBFX will becomebecame an indirect wholly-owned subsidiary of PBF Energy and PBF LLC.
The Merger Transaction is subject
Business Developments
Recent significant business developments affecting us are discussed below.
Distribution of assets
On June 27, 2023, we distributed to customary closing conditions and the approval of the PBFX common unitholders (including PBF Energy). The transaction is expectedLLC, which in turn contributed to closeSt. Bernard Renewables LLC (“SBR”), approximately $739.8 million in the fourth quarter of 2022, however there can be no assurance that the Merger Transaction will be consummated in the anticipated timeframe, on the contemplated terms or at all.
Market Developments
We continue to adjust our operational plansassets related to the evolving market conditions and continue to monitor and manage operating expenses through reductions in discretionary activities and third-party services. Market conditions currently include high crude oil prices, tight domestic supplies and elevated refining margins as a result of sustained increases in demand, coupled with global supply disruption related to sanctions imposed on Russia for its invasion of Ukraine.
Renewable Diesel Project
We continue to advance our project for a renewable fuels productiondiesel facility co-located at ourwith the Company’s Chalmette refinery in Louisiana (the “Renewable Diesel Project”Facility”). The project incorporates certain idled assets at the refinery, including an idle hydrocracker, along withWe have no interest in SBR, which is jointly owned by a newly-constructed pre-treatment unitsubsidiary of PBF LLC and its partner, Eni Sustainable Mobility US Inc., a subsidiary of Eni SpA. Additionally, we distributed to establish a 20,000 barrel per day renewable diesel production facility. During the third quarterPBF LLC, which in turn contributed to one of 2022, we investedits subsidiaries, Chalmette Refining Service Company LLC (“CRSC”), approximately $103.0$103.8 million in capital to progress and incubate the project with the goal of beingassets. The Company has no interest in production in the first half of 2023. Concurrent with our activities to progress the project, we are continuing discussions with potential strategic and financial partners.CRSC, which is owned by PBF LLC.
Factors Affecting Comparability Between Periods
Our results have been affected by the following events, the understanding of which will aid in assessing the comparability of our period to period financial performance and financial condition.
Debt and Credit Facilities
Senior Notes
During the three months ended September 30, 2022, we exercised our rights under the indenture governing the 9.25% senior secured notes due 2025 (the “2025 Senior Secured Notes”) to redeem all of the outstanding 2025 Senior Secured Notes at a price of 104.625% of the aggregate principal amount thereof plus accrued and unpaid interest. The aggregate redemption price for all 2025 Senior Secured Notes approximated $1.3 billion plus accrued and unpaid interest. The difference between the carrying value of the 2025 Senior Secured Notes on the date they were redeemed and the amount for which they were redeemed was $69.9 million and was recorded as a loss on extinguishment of debt in the Consolidated Statements of Operations.
During the nine months ended September 30, 2022, we made a number of open market repurchases of our 6.00% senior unsecured notes due 2028 (the “2028 Senior Notes”) and 7.25% senior unsecured notes due 2025 (the “2025 Senior Notes”) that resulted in the extinguishment of $24.9 million in principal of the 2028 Senior Notes and $5.0 million in principal of the 2025 Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, totaled $25.9 million and we recognized a $3.8 million gain on the extinguishment of debt during the nine months ended September 30, 2022.
During the three months ended September 30, 2021, we made a number of open market purchases of our 2028 Senior Notes and our 2025 Senior Notes that resulted in the extinguishment of $117.7 million in principal of the 2028 Senior Notes and $35.0 million in principal of the 2025 Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, totaled $90.9 million and we recognized a $60.3 million gain on the extinguishment of debt during the three and nine months ended September 30, 2021.
Revolving Credit Facility
On May 25, 2022, we entered into an amendment of our existing asset-based revolving credit agreement (the “Revolving Credit Agreement”). Among other things, the Revolving Credit Agreement amended and extended PBF Holding’s asset-based revolving credit facility (the “Revolving Credit Facility”) through January 2025 and increased the maximum commitment to $4.3 billion through May 2023 (currently set to adjust to $2.75 billion in May 2023 through January 2025). The amendments also redefine certain components of the Borrowing Base (as defined in the Revolving Credit Agreement) to reflect the existence of the two tranches, tranche A which is comprised of existing lenders who have not elected to extend and whose commitments retain the existing maturity date under the existing revolving credit agreement of May 2, 2023 (the “Tranche A Commitments”) and tranche B, which is comprised of existing and new lenders whose commitments have an extended maturity date of January 31, 2025 (the “Tranche B Commitments”). The Tranche A Commitments total $1.55 billion and the Tranche B Commitments total $2.75 billion. The amendments also include changes to incorporate the adoption of Secured Overnight Financing Rate (“SOFR”) as a replacement of the London Interbank Offered Rate (“LIBOR”), changes to joint lead arrangers, bookrunners, syndication agents and other titles, and other changes related to the foregoing. In addition, an accordion feature allows for additional Tranche B Commitments of up to an additional $500.0 million plus an amount equal to the Tranche A Commitments for existing Tranche A lenders.
During the nine months ended September 30, 2022, we made net repayments of $900.0 million on the Revolving Credit Facility, resulting in no outstanding borrowings as of September 30, 2022. There was $900.0 million of outstanding borrowings under the Revolving Credit Facility as of December 31, 2021.
Catalyst Financing Obligations
During the three months ended September 30, 2022 and September 30, 2021, we settled certain of our precious metals financing arrangements, which represented a reduction of debt of approximately $37.3 million and $18.5 million, respectively.
Agreements with PBFX
PBFX is a fee-based, growth-oriented, publicly traded Delaware master limited partnership formed by our indirect parent company, PBF Energy, to own or lease, operate, develop and acquire crude oil, refined petroleum products and natural gas terminals, pipelines, storage facilities and similar logistics assets. PBFX engages in the receiving, handling, storage and transferring of crude oil, refined products, natural gas and intermediates from sources located throughout the United States and Canada for PBF Energy in support of certain of our refineries, as well as for third-party customers.
We have entered into a series of agreements with PBFX, including contribution, commercial and operational agreements. Refer to “Note 6 - Related Party Transactions” of our Notes to Condensed Consolidated Financial Statements for descriptions of these agreements and their impact to our operations. Related party transactions that have an impact on the comparability of our period to period financial performance and financial condition are listed below.
Summary of Transactions with PBFX
A summary of affiliate transactions with PBFX is as follows (in millions):follows:
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| 2022 | | 2021 | | 2022 | | 2021 | |
| (in millions) | | (in millions) | 2023 | | 2022 | | 2023 | | 2022 |
| Reimbursements under affiliate agreements: | Reimbursements under affiliate agreements: | | Reimbursements under affiliate agreements: | |
| Services Agreement | Services Agreement | $ | 2.2 | | | $ | 2.2 | | | $ | 6.5 | | | $ | 6.5 | | Services Agreement | $ | 2.1 | | | $ | 2.1 | | | $ | 4.3 | | | $ | 4.3 | |
| Omnibus Agreement | Omnibus Agreement | 2.1 | | | 1.8 | | | 6.2 | | | 5.5 | | Omnibus Agreement | 2.1 | | | 2.3 | | | 3.9 | | | 4.1 | |
| Total expenses under affiliate agreements | Total expenses under affiliate agreements | 77.4 | | | 75.5 | | | 233.0 | | | 226.5 | | Total expenses under affiliate agreements | 84.8 | | | 79.6 | | | 173.8 | | | 155.6 | |
Results of Operations
The following tables reflect our financial and operating highlights for the three and ninesix months ended SeptemberJune 30, 20222023 and 20212022 (amounts in millions):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | 2023 | | 2022 |
| Revenues | Revenues | $ | 12,752.3 | | | $ | 7,173.3 | | | $ | 35,944.5 | | | $ | 18,969.7 | | Revenues | $ | 9,148.4 | | | $ | 14,064.0 | | | $ | 18,433.9 | | | $ | 23,192.2 | |
| Cost and expenses: | Cost and expenses: | | Cost and expenses: | |
| Cost of products and other | Cost of products and other | 10,490.2 | | | 6,445.8 | | | 30,223.5 | | | 16,880.7 | | Cost of products and other | 7,988.2 | | | 11,455.8 | | | 15,867.9 | | | 19,733.3 | |
| Operating expenses (excluding depreciation and amortization expense as reflected below) | Operating expenses (excluding depreciation and amortization expense as reflected below) | 620.1 | | | 507.6 | | | 1,829.5 | | | 1,430.1 | | Operating expenses (excluding depreciation and amortization expense as reflected below) | 571.4 | | | 613.8 | | | 1,320.4 | | | 1,209.4 | |
| Depreciation and amortization expense | Depreciation and amortization expense | 119.1 | | | 103.0 | | | 338.9 | | | 310.0 | | Depreciation and amortization expense | 133.0 | | | 110.9 | | | 265.9 | | | 219.8 | |
| Cost of sales | Cost of sales | 11,229.4 | | | 7,056.4 | | | 32,391.9 | | | 18,620.8 | | Cost of sales | 8,692.6 | | | 12,180.5 | | | 17,454.2 | | | 21,162.5 | |
| General and administrative expenses (excluding depreciation and amortization expense as reflected below) | General and administrative expenses (excluding depreciation and amortization expense as reflected below) | 161.7 | | | 59.7 | | | 356.9 | | | 150.5 | | General and administrative expenses (excluding depreciation and amortization expense as reflected below) | 100.8 | | | 145.9 | | | 157.9 | | | 195.2 | |
| Depreciation and amortization expense | Depreciation and amortization expense | 2.0 | | | 3.4 | | | 5.8 | | | 10.1 | | Depreciation and amortization expense | 2.3 | | | 1.9 | | | 4.2 | | | 3.8 | |
| Change in fair value of contingent consideration | 3.0 | | | (0.7) | | | 130.7 | | | 23.6 | | |
| Change in fair value of contingent consideration, net | | Change in fair value of contingent consideration, net | (16.6) | | | 77.6 | | | (32.9) | | | 127.7 | |
| | Loss (gain) on sale of assets | Loss (gain) on sale of assets | — | | | 0.2 | | | 0.3 | | | (0.4) | | Loss (gain) on sale of assets | 0.2 | | | 0.2 | | | (1.4) | | | 0.3 | |
| Total cost and expenses | Total cost and expenses | 11,396.1 | | | 7,119.0 | | | 32,885.6 | | | 18,804.6 | | Total cost and expenses | 8,779.3 | | | 12,406.1 | | | 17,582.0 | | | 21,489.5 | |
| Income from operations | Income from operations | 1,356.2 | | | 54.3 | | | 3,058.9 | | | 165.1 | | Income from operations | 369.1 | | | 1,657.9 | | | 851.9 | | | 1,702.7 | |
| Other income (expense): | Other income (expense): | | Other income (expense): | |
| Interest expense, net | Interest expense, net | (43.1) | | | (71.5) | | | (186.7) | | | (211.0) | | Interest expense, net | (15.1) | | | (75.4) | | | (30.0) | | | (143.6) | |
| Change in fair value of catalyst obligations | Change in fair value of catalyst obligations | (2.6) | | | 17.8 | | | (0.3) | | | 13.6 | | Change in fair value of catalyst obligations | 0.5 | | | 7.2 | | | 1.2 | | | 2.3 | |
| (Loss) gain on extinguishment of debt | (69.9) | | | 60.3 | | | (66.1) | | | 60.3 | | |
| Gain on extinguishment of debt | | Gain on extinguishment of debt | — | | | 3.8 | | | — | | | 3.8 | |
| Other non-service components of net periodic benefit cost | Other non-service components of net periodic benefit cost | 2.2 | | | 2.0 | | | 6.6 | | | 5.9 | | Other non-service components of net periodic benefit cost | 0.1 | | | 2.2 | | | 0.4 | | | 4.4 | |
| Income before income taxes | Income before income taxes | 1,242.8 | | | 62.9 | | | 2,812.4 | | | 33.9 | | Income before income taxes | 354.6 | | | 1,595.7 | | | 823.5 | | | 1,569.6 | |
| Income tax expense (benefit) | 10.4 | | | (2.0) | | | 1.1 | | | (16.9) | | |
| Income tax benefit | | Income tax benefit | — | | | (1.2) | | | (0.6) | | | (9.3) | |
| Net income | Net income | 1,232.4 | | | 64.9 | | | 2,811.3 | | | 50.8 | | Net income | 354.6 | | | 1,596.9 | | | 824.1 | | | 1,578.9 | |
| Less: net income (loss) attributable to noncontrolling interests | Less: net income (loss) attributable to noncontrolling interests | 0.3 | | | (0.1) | | | (1.4) | | | 2.3 | | Less: net income (loss) attributable to noncontrolling interests | 0.1 | | | (0.6) | | | 0.4 | | | (1.7) | |
| Net income attributable to PBF Holding Company LLC | Net income attributable to PBF Holding Company LLC | $ | 1,232.1 | | | $ | 65.0 | | | $ | 2,812.7 | | | $ | 48.5 | | Net income attributable to PBF Holding Company LLC | $ | 354.5 | | | $ | 1,597.5 | | | $ | 823.7 | | | $ | 1,580.6 | |
| Consolidated gross margin | Consolidated gross margin | $ | 1,522.9 | | | $ | 116.9 | | | $ | 3,552.6 | | | $ | 348.9 | | Consolidated gross margin | $ | 455.8 | | | $ | 1,883.5 | | | $ | 979.7 | | | $ | 2,029.7 | |
Gross refining margin (1) | Gross refining margin (1) | $ | 2,262.1 | | | $ | 727.5 | | | $ | 5,721.0 | | | $ | 2,089.0 | | Gross refining margin (1) | $ | 1,160.2 | | | $ | 2,608.2 | | | $ | 2,566.0 | | | $ | 3,458.9 | |
|
_____________________
(1) See Non-GAAP Financial Measures.
| | Operating Highlights | Operating Highlights | Three Months Ended September 30, | | Nine Months Ended September 30, | Operating Highlights | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | 2023 | | 2022 |
| Key Operating Information | Key Operating Information | | | | | | | | Key Operating Information | | | | | | | |
| Production (bpd in thousands) | Production (bpd in thousands) | 996.7 | | | 867.7 | | | 933.7 | | | 839.7 | | Production (bpd in thousands) | 945.7 | | | 958.8 | | | 902.3 | | | 901.6 | |
| Crude oil and feedstocks throughput (bpd in thousands) | Crude oil and feedstocks throughput (bpd in thousands) | 984.7 | | | 848.3 | | | 920.4 | | | 823.2 | | Crude oil and feedstocks throughput (bpd in thousands) | 935.8 | | | 942.2 | | | 893.7 | | | 887.7 | |
| Total crude oil and feedstocks throughput (millions of barrels) | Total crude oil and feedstocks throughput (millions of barrels) | 90.6 | | | 78.0 | | | 251.3 | | | 224.7 | | Total crude oil and feedstocks throughput (millions of barrels) | 85.2 | | | 85.8 | | | 161.8 | | | 160.7 | |
| Consolidated gross margin per barrel of throughput | Consolidated gross margin per barrel of throughput | $ | 16.81 | | | $ | 1.50 | | | $ | 14.14 | | | $ | 1.56 | | Consolidated gross margin per barrel of throughput | $ | 5.35 | | | $ | 21.96 | | | $ | 6.06 | | | $ | 12.64 | |
Gross refining margin, excluding special items, per barrel of throughput (1) | Gross refining margin, excluding special items, per barrel of throughput (1) | $ | 24.96 | | | $ | 9.32 | | | $ | 22.77 | | | $ | 6.32 | | Gross refining margin, excluding special items, per barrel of throughput (1) | $ | 13.62 | | | $ | 30.41 | | | $ | 15.86 | | | $ | 21.54 | |
| Refinery operating expense, per barrel of throughput | Refinery operating expense, per barrel of throughput | $ | 6.84 | | | $ | 6.50 | | | $ | 7.28 | | | $ | 6.36 | | Refinery operating expense, per barrel of throughput | $ | 6.71 | | | $ | 7.16 | | | $ | 8.16 | | | $ | 7.53 | |
| Crude and feedstocks (% of total throughput) (2) | Crude and feedstocks (% of total throughput) (2) | | Crude and feedstocks (% of total throughput) (2) | |
| Heavy | Heavy | 31 | % | | 32 | % | | 32 | % | | 34 | % | Heavy | 27 | % | | 31 | % | | 27 | % | | 33 | % |
| Medium | Medium | 39 | % | | 32 | % | | 35 | % | | 29 | % | Medium | 35 | % | | 34 | % | | 34 | % | | 33 | % |
| Light | Light | 17 | % | | 19 | % | | 19 | % | | 20 | % | Light | 21 | % | | 20 | % | | 21 | % | | 19 | % |
| Other feedstocks and blends | Other feedstocks and blends | 13 | % | | 17 | % | | 14 | % | | 17 | % | Other feedstocks and blends | 17 | % | | 15 | % | | 18 | % | | 15 | % |
| Total throughput | Total throughput | 100 | % | | 100 | % | | 100 | % | | 100 | % | Total throughput | 100 | % | | 100 | % | | 100 | % | | 100 | % |
| | Yield (% of total throughput) | Yield (% of total throughput) | | Yield (% of total throughput) | |
| Gasoline and gasoline blendstocks | Gasoline and gasoline blendstocks | 47 | % | | 52 | % | | 47 | % | | 53 | % | Gasoline and gasoline blendstocks | 48 | % | | 47 | % | | 48 | % | | 48 | % |
| Distillates and distillate blendstocks | Distillates and distillate blendstocks | 35 | % | | 29 | % | | 35 | % | | 30 | % | Distillates and distillate blendstocks | 33 | % | | 36 | % | | 33 | % | | 35 | % |
| Lubes | Lubes | 1 | % | | 1 | % | | 1 | % | | 1 | % | Lubes | 1 | % | | 1 | % | | 1 | % | | 1 | % |
| Chemicals | Chemicals | 1 | % | | 2 | % | | 2 | % | | 2 | % | Chemicals | 1 | % | | 1 | % | | 1 | % | | 2 | % |
| Other | Other | 17 | % | | 18 | % | | 16 | % | | 16 | % | Other | 18 | % | | 17 | % | | 18 | % | | 16 | % |
| Total yield | Total yield | 101 | % | | 102 | % | | 101 | % | | 102 | % | Total yield | 101 | % | | 102 | % | | 101 | % | | 102 | % |
_____________________
(1) See Non-GAAP Financial Measures.
(2) We define heavy crude oil as crude oil with American Petroleum Institute (“API”) gravity of less than 24 degrees. We define medium crude oil as crude oil with an API gravity between 24 and 35 degrees. We define light crude oil as crude oil with an API gravity higher than 35 degrees.
The table below summarizes certain market indicators relating to our operating results as reported by Platts.Platts, a division of The McGraw-Hill Companies. Effective RIN basket price is recalculated based on information as reported by Argus.
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | 2023 | | 2022 |
| | (dollars per barrel, except as noted) | | (dollars per barrel, except as noted) |
| Dated Brent crude oil | Dated Brent crude oil | $ | 100.49 | | | $ | 73.45 | | | $ | 105.34 | | | $ | 67.93 | | Dated Brent crude oil | $ | 78.21 | | | $ | 113.93 | | | $ | 79.65 | | | $ | 107.84 | |
| West Texas Intermediate (WTI) crude oil | West Texas Intermediate (WTI) crude oil | $ | 91.63 | | | $ | 70.54 | | | $ | 98.46 | | | $ | 65.06 | | West Texas Intermediate (WTI) crude oil | $ | 73.56 | | | $ | 108.77 | | | $ | 74.76 | | | $ | 101.99 | |
| Light Louisiana Sweet (LLS) crude oil | Light Louisiana Sweet (LLS) crude oil | $ | 94.03 | | | $ | 71.46 | | | $ | 100.55 | | | $ | 66.68 | | Light Louisiana Sweet (LLS) crude oil | $ | 75.62 | | | $ | 110.33 | | | $ | 77.26 | | | $ | 103.91 | |
| Alaska North Slope (ANS) crude oil | Alaska North Slope (ANS) crude oil | $ | 98.84 | | | $ | 72.66 | | | $ | 102.34 | | | $ | 67.53 | | Alaska North Slope (ANS) crude oil | $ | 78.26 | | | $ | 112.17 | | | $ | 78.64 | | | $ | 104.15 | |
| Crack Spreads | Crack Spreads | | Crack Spreads | |
| Dated Brent (NYH) 2-1-1 | Dated Brent (NYH) 2-1-1 | $ | 37.51 | | | $ | 18.66 | | | $ | 38.14 | | | $ | 16.09 | | Dated Brent (NYH) 2-1-1 | $ | 28.66 | | | $ | 55.26 | | | $ | 30.09 | | | $ | 38.47 | |
| WTI (Chicago) 4-3-1 | WTI (Chicago) 4-3-1 | $ | 35.35 | | | $ | 19.60 | | | $ | 32.63 | | | $ | 16.73 | | WTI (Chicago) 4-3-1 | $ | 27.82 | | | $ | 44.53 | | | $ | 28.44 | | | $ | 31.24 | |
| LLS (Gulf Coast) 2-1-1 | LLS (Gulf Coast) 2-1-1 | $ | 38.75 | | | $ | 18.13 | | | $ | 37.77 | | | $ | 15.40 | | LLS (Gulf Coast) 2-1-1 | $ | 26.41 | | | $ | 50.39 | | | $ | 30.26 | | | $ | 37.27 | |
| ANS (West Coast-LA) 4-3-1 | ANS (West Coast-LA) 4-3-1 | $ | 46.87 | | | $ | 21.54 | | | $ | 44.45 | | | $ | 19.58 | | ANS (West Coast-LA) 4-3-1 | $ | 33.73 | | | $ | 53.56 | | | $ | 36.08 | | | $ | 43.20 | |
| ANS (West Coast-SF) 3-2-1 | ANS (West Coast-SF) 3-2-1 | $ | 47.97 | | | $ | 23.27 | | | $ | 44.54 | | | $ | 19.22 | | ANS (West Coast-SF) 3-2-1 | $ | 33.56 | | | $ | 56.14 | | | $ | 36.36 | | | $ | 42.76 | |
| Crude Oil Differentials | Crude Oil Differentials | | Crude Oil Differentials | |
| Dated Brent (foreign) less WTI | Dated Brent (foreign) less WTI | $ | 8.86 | | | $ | 2.91 | | | $ | 6.87 | | | $ | 2.87 | | Dated Brent (foreign) less WTI | $ | 4.65 | | | $ | 5.16 | | | $ | 4.89 | | | $ | 5.85 | |
| Dated Brent less Maya (heavy, sour) | Dated Brent less Maya (heavy, sour) | $ | 16.10 | | | $ | 7.26 | | | $ | 12.81 | | | $ | 5.93 | | Dated Brent less Maya (heavy, sour) | $ | 14.70 | | | $ | 9.99 | | | $ | 16.58 | | | $ | 11.11 | |
| Dated Brent less WTS (sour) | Dated Brent less WTS (sour) | $ | 8.26 | | | $ | 2.91 | | | $ | 6.89 | | | $ | 2.53 | | Dated Brent less WTS (sour) | $ | 4.76 | | | $ | 5.64 | | | $ | 5.18 | | | $ | 6.19 | |
| Dated Brent less ASCI (sour) | Dated Brent less ASCI (sour) | $ | 11.22 | | | $ | 4.79 | | | $ | 9.55 | | | $ | 3.58 | | Dated Brent less ASCI (sour) | $ | 5.17 | | | $ | 8.75 | | | $ | 6.28 | | | $ | 8.69 | |
| WTI less WCS (heavy, sour) | WTI less WCS (heavy, sour) | $ | 22.61 | | | $ | 13.59 | | | $ | 18.74 | | | $ | 13.00 | | WTI less WCS (heavy, sour) | $ | 13.49 | | | $ | 18.52 | | | $ | 16.42 | | | $ | 16.96 | |
| WTI less Bakken (light, sweet) | WTI less Bakken (light, sweet) | $ | (4.77) | | | $ | (0.48) | | | $ | (4.08) | | | $ | 0.07 | | WTI less Bakken (light, sweet) | $ | (1.74) | | | $ | (3.97) | | | $ | (2.32) | | | $ | (3.73) | |
| WTI less Syncrude (light, sweet) | WTI less Syncrude (light, sweet) | $ | (6.30) | | | $ | 2.47 | | | $ | (3.54) | | | $ | 1.66 | | WTI less Syncrude (light, sweet) | $ | (2.88) | | | $ | (4.38) | | | $ | (2.99) | | | $ | (2.03) | |
| WTI less LLS (light, sweet) | WTI less LLS (light, sweet) | $ | (2.40) | | | $ | (0.92) | | | $ | (2.08) | | | $ | (1.63) | | WTI less LLS (light, sweet) | $ | (2.05) | | | $ | (1.56) | | | $ | (2.50) | | | $ | (1.92) | |
| WTI less ANS (light, sweet) | WTI less ANS (light, sweet) | $ | (7.21) | | | $ | (2.12) | | | $ | (3.88) | | | $ | (2.48) | | WTI less ANS (light, sweet) | $ | (4.70) | | | $ | (3.40) | | | $ | (3.87) | | | $ | (2.16) | |
| Effective RIN basket price | | Effective RIN basket price | $ | 7.68 | | | $ | 7.68 | | | $ | 7.93 | | | $ | 6.98 | |
| Natural gas (dollars per MMBTU) | Natural gas (dollars per MMBTU) | $ | 7.95 | | | $ | 4.32 | | | $ | 6.69 | | | $ | 3.35 | | Natural gas (dollars per MMBTU) | $ | 2.33 | | | $ | 7.50 | | | $ | 2.54 | | | $ | 6.04 | |
Three Months Ended SeptemberJune 30, 20222023 Compared to the Three Months Ended SeptemberJune 30, 20212022
Overview— Net income was $1,232.4$354.6 million for the three months ended SeptemberJune 30, 20222023 compared to net income of $64.9$1,596.9 million for the three months ended SeptemberJune 30, 2021.2022.
Our results for the three months ended SeptemberJune 30, 20222023 were negativelypositively impacted by a special itemsitem consisting of a loss on extinguishment of debt associated with the redemption of our 2025 Senior Secured Notes of $69.9 million and a change in fair value of the contingent consideration associated with the acquisition of the Martinez refinery and logistic assets (the “Martinez Contingent Consideration”) of $3.0$16.6 million. Our results for the three months ended SeptemberJune 30, 20212022 were positivelynegatively impacted by special items consisting of a change in fair value of the Martinez Contingent Consideration of $77.6 million, partially offset by a gain on the extinguishment of debt associated with the repurchase of a portion of ourthe 6.0% senior unsecured notes due 2028 (the “2028 Senior NotesNotes”) and ourthe 7.25% senior unsecured notes due 2025 (the “2025 Senior NotesNotes”) of $60.3 million, and a change in the fair value of the Martinez Contingent Consideration of $0.7$3.8 million.
Excluding the impact of these special items, when comparing our results to the three months ended SeptemberJune 30, 2021, we experienced an increase in the demand for our2022, refined products evidencedmargins were less favorable as the prior year benefited from global supply disruption, caused in large part by higherthe conflict between Russia and Ukraine. In addition, our results for the three months ended June 30, 2023 were impacted by lower average throughput volumes and on average less barrels sold at allthe majority of our refineries as well as overall stronger margins due to favorable movements in crack spreads and crude oil differentials. These improving metrics have positively impacted our revenues, gross margin and operating income.
a year-over-year higher level of planned maintenance activity.Revenues— Revenues totaled $12.8$9.1 billion for the three months ended SeptemberJune 30, 20222023 compared to $7.2$14.1 billion for the three months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $5.6$5.0 billion, or 77.8%35.5%. Revenues per barrel were $126.44$95.56 and $83.29$146.12 for the three months ended SeptemberJune 30, 2023 and 2022, and 2021, respectively, an increasea decrease of 51.8%34.6% directly related to higherlower hydrocarbon commodity prices. For the three months ended SeptemberJune 30, 2023, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 304,100 bpd, 158,500 bpd, 169,300 bpd and 303,900 bpd, respectively. For the three months ended June 30, 2022, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 318,900292,100 bpd, 159,300161,700 bpd, 192,500199,500 bpd and 314,000288,900 bpd, respectively. For the three months ended SeptemberJune 30, 2021,2023, the total throughput ratesbarrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 259,800348,300 bpd, 146,000162,900 bpd, 145,300178,100 bpd and 297,200362,800 bpd, respectively. For the three months ended SeptemberJune 30, 2022, the total barrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 372,000339,500 bpd, 168,000167,500 bpd, 198,900213,900 bpd and 357,400 bpd, respectively. For the three months ended September 30, 2021, the total barrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 299,300 bpd, 152,800 bpd, 152,000 bpd and 332,100336,800 bpd, respectively.
TheAverage throughput rates at our refineries were higherlower in the three months ended SeptemberJune 30, 20222023 compared to the same period in 2021.2022. We plan to continue operating our refineries based on demand and current market conditions. Total refined product barrels sold were higher than throughput rates, reflecting sales from inventory as well as sales and purchases of refined products outside our refineries.
Consolidated Gross Margin— Consolidated gross margin totaled $1,522.9$455.8 million for the three months ended SeptemberJune 30, 20222023 compared to $116.9$1,883.5 million for the three months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $1,406.0$1,427.7 million. Gross refining margin (as described below in Non-GAAP Financial Measures) and gross refining margin excluding special items totaled $2,262.1$1,160.2 million, or $24.96$13.62 per barrel of throughput for the three months ended SeptemberJune 30, 20222023 compared to $727.5$2,608.2 million, or $9.32$30.41 per barrel of throughput for the three months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $1,534.6$1,448.0 million.
During the three months ended SeptemberJune 30, 20222023 and SeptemberJune 30, 2021,2022, our margin calculations were not impacted by special items. Consolidated gross margin and gross refining margin increaseddecreased due to favorableunfavorable movements in certain crack spreads and crude oil differentials and higherlower throughput volumes and barrels sold at allcertain of our refineries.
Additionally, our results continue to be impacted by significant costs to comply with the Renewable Fuel Standard.RFS. Total Renewable Fuel StandardRFS compliance costs were $297.6$289.1 million for the three months ended SeptemberJune 30, 20222023 in comparison to $73.1$432.7 million for three months ended months ended SeptemberJune 30, 2021.2022.
Average industry margins were favorablelower during the three months ended SeptemberJune 30, 20222023 in comparison to the same period in 2021,2022, primarily due to increasesdecreases in regional demand and favorablelower movements in refining margins as a result of global supply disruptions.lower crack spreads and crude oil differentials.
Favorable movements in benchmark crude differentials typically result in lower crude costs and positively impact our earnings while reductions in these benchmark crude differentials typically result in higher crude costs and negatively impact our earnings.
On the East Coast, the Dated Brent (NYH) 2-1-1 industry crack spread was approximately $37.51$28.66 per barrel, or 101.0% higher,48.1% lower, in the three months ended SeptemberJune 30, 2022,2023, as compared to $18.66$55.26 per barrel in the same period in 2021.2022. Our margins were positively impacted from our refinery specific slate on the East Coast by strengthening Dated Brent/Maya differential,and WTI/Bakken differentials, which increased by $8.84$4.71 and $2.23 per barrel, partially offset by weakened WTI/Bakken differentials, which decreased by $4.29 per barrelrespectively, in comparison to the same period in 2021.2022. The WTI/WCS differential increaseddecreased to $22.61$13.49 per barrel in the three months ended SeptemberJune 30, 20222023 compared to $13.59$18.52 in the same period in 2021,2022, which favorablyunfavorably impacted our cost of heavy Canadian crude.
Across the Mid-Continent, the WTI (Chicago) 4-3-1 industry crack spread was $35.35$27.82 per barrel, or 80.4% higher,37.5% lower, in the three months ended SeptemberJune 30, 20222023 as compared to $19.60$44.53 per barrel in the same period in 2021.2022. Our margins were negativelypositively impacted from our refinery specific slate in the Mid-Continent by a decreasingan increasing WTI/Bakken differential, which averaged a premium of $4.77$1.74 per barrel in the three months ended SeptemberJune 30, 2022,2023, as compared to a premium of $0.48$3.97 per barrel in the same period in 2021.2022. Additionally, the WTI/Syncrude differential averaged a premium $6.30$2.88 per barrel during the three months ended SeptemberJune 30, 20222023 as compared to a discountpremium of $2.47$4.38 per barrel in the same period of 2021.2022.
On the Gulf Coast, the LLS (Gulf Coast) 2-1-1 industry crack spread was $38.75$26.41 per barrel, or 113.7% higher,47.6% lower, in the three months ended SeptemberJune 30, 20222023 as compared to $18.13$50.39 per barrel in the same period in 2021.2022. Margins on the Gulf Coast were negatively impacted from our refinery specific slate by a weakened WTI/LLS differential, which averaged a premium of $2.40$2.05 per barrel during the three months ended SeptemberJune 30, 20222023 as compared to a premium of $0.92$1.56 per barrel in the same period of 2021.2022.
On the West Coast the ANS (West Coast) 4-3-1 industry crack spread was $46.87$33.73 per barrel, or 117.6% higher,37.0% lower, in the three months ended SeptemberJune 30, 20222023 as compared to $21.54$53.56 per barrel in the same period in 2021.2022. Additionally, the ANS (West Coast) 3-2-1 industry crack spread was $47.97$33.56 per barrel, or 106.1% higher,40.2% lower, in the three months ended SeptemberJune 30, 20222023 as compared to $23.27$56.14 per barrel in the same period in 2021.2022. Our margins on the West Coast were negatively impacted from our refinery specific slate by weakened WTI/ANS differential, which averaged a premium of $7.21$4.70 per barrel during the three months ended SeptemberJune 30, 20222023 as compared to a premium of $2.12$3.40 per barrel in the same period of 2021.2022.
Operating Expenses— Operating expenses totaled $620.1$571.4 million, or $6.84$6.71 per barrel of throughput, for the three months ended SeptemberJune 30, 20222023 compared to $507.6$613.8 million, or $6.50$7.16 per barrel of throughput, for the three months ended SeptemberJune 30, 2021, an increase2022, a decrease of $112.5$42.4 million, or 22.2%6.9%. The increasedecrease in operating expenses was mainly attributable to increasesdecreases in natural gas volumes and priceprices across our refineries when compared to the same period in 2021. Additionally, we experienced higher outside services, maintenance and operational costs due to increased production.2022.
General and Administrative Expenses— General and administrative expenses totaled $161.7$100.8 million for the three months ended SeptemberJune 30, 20222023 compared to $59.7$145.9 million for the three months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $102.0$45.1 million or 170.9%30.9%. The increasedecrease in general and administrative expenses for the three months ended SeptemberJune 30, 20222023 in comparison to the three months ended SeptemberJune 30, 20212022 is primarily related to higherlower employee-related expenses, including the recognition of incentive compensation for our non-executive employees.compensation. Our general and administrative expenses are comprised of personnel, facilities and other infrastructure costs necessary to support our refineries.
Loss (Gain) on Sale of Assets— There was no gain ora loss on the sale of assets$0.2 million for both the three months ended SeptemberJune 30, 2022. There was a loss on the sale of assets of $0.2 million for the three months ended September2023 and June 30, 20212022, related primarily to the sale of non-operating refinery assets.
Depreciation and Amortization Expense— Depreciation and amortization expense totaled $121.1$135.3 million for the three months ended SeptemberJune 30, 20222023 (including $119.1$133.0 million recorded within Cost of sales) compared to $106.4$112.8 million for the three months ended SeptemberJune 30, 20212022 (including $103.0$110.9 million recorded within Cost of sales), an increase of $14.7$22.5 million. The increase was a result of a general increase to our fixed asset base due to capital projects and turnarounds completed since the thirdsecond quarter of 2021.2022.
Change in Fair Value of Contingent Consideration— Change in fair value of contingent consideration represented a lossgain of $3.0$16.6 million and a gainloss of $0.7$77.6 million for the three months ended SeptemberJune 30, 2023 and June 30, 2022, and September 30, 2021, respectively. These lossesgains and gainslosses were related to the changes in estimated fair value of the Martinez Contingent Consideration.
Change in Fair Value of Catalyst Obligations— Change in fair value of catalyst obligations represented a lossgain of $2.6$0.5 million for the three months ended SeptemberJune 30, 20222023 compared to a gain of $17.8$7.2 million for the three months ended SeptemberJune 30, 2021.2022. These losses and gains relate to the change in value of the precious metals underlying the sale and leaseback of our refineries’ precious metal catalysts, which we are obligated to repurchase at fair market value upon lease termination.
(Loss) Gain on Extinguishment of Debt— LossThere was no gain or loss on the extinguishment of debt for the three months ended June 30, 2023. There was a gain on the extinguishment of debt of $69.9$3.8 million incurred in the three months ended SeptemberJune 30, 2022, relates to the redemption of the outstanding 2025 Senior Secured Notes. There was a gain on extinguishment of debt of $60.3 million related to the repurchase of a portion of our 2028 Senior Notes and 2025 Senior Notes in the same period of 2021.Notes.
Interest Expense, net— Interest expense totaled $43.1$15.1 million for the three months ended SeptemberJune 30, 20222023 compared to $71.5$75.4 million for the three months ended SeptemberJune 30, 2021,2022, a decrease of approximately $28.4$60.3 million. The net decrease is mainly attributed to the redemption of the 9.25% senior secured notes due 2025 (the “2025 Senior Secured NotesNotes”) during the third quarter of 2022, as well as a lowerno outstanding balance on our Revolvingthe PBF Holding’s asset-based revolving credit facility (the “Revolving Credit FacilityFacility”) as of SeptemberJune 30, 2022.2023. Additionally, there was a $10.8 million increase in interest income earned during the three months ended June 30, 2023 driven by higher interest rates in comparison to the same period in the prior year. Interest expense includes interest on long-term debt, costs related to the sale and leaseback of our precious metal catalysts, financing costs associated with the Thirdour third amended and restated inventory intermediation agreement (the “Third Inventory Intermediation AgreementAgreement”) with J. Aron & Company, a subsidiary of the Goldman Sachs Group, Inc. (“J. Aron”), which was terminated effective as of July 31, 2023, letter of credit fees associated with the purchase of certain crude oils and the amortization of deferred financing costs.
Income Tax Expense— As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, our Condensed Consolidated Financial Statements generally do not include a benefit or expense for income taxes for the three months ended SeptemberJune 30, 20222023 and SeptemberJune 30, 2021,2022, respectively, apart from the income tax attributable to two subsidiaries acquired in connection with the Chalmette refinery in the fourth quarter of 2015 and PBF Energy Limited (“PBF Ltd.”). These subsidiaries are treated as C-Corporations for income tax purposes. AnA de minimis income tax expense of $10.4 millionbenefit was recorded for the three months ended SeptemberJune 30, 20222023 in comparison to an income tax benefit of $2.0$1.2 million recorded for the three months ended SeptemberJune 30, 2021,2022, primarily attributable to the results of PBF Ltd.
NineSix Months Ended SeptemberJune 30, 20222023 Compared to the NineSix Months Ended SeptemberJune 30, 20212022
Overview— Net income was $2,811.3$824.1 million for the ninesix months ended SeptemberJune 30, 20222023 compared to net income of $50.8$1,578.9 million for the ninesix months ended SeptemberJune 30, 2021.2022.
Our results for the ninesix months ended SeptemberJune 30, 2023 were positively impacted by special items consisting of a change in fair value of contingent consideration of $32.9 million related to changes in the estimated fair value of the Martinez Contingent Consideration, and a gain on the sale of a parcel of land at our Torrance refinery of $1.7 million. Our results for the six months ended June 30, 2022 were negatively impacted by special items consisting of a net loss on the extinguishment of debt mainly associated with the redemption of our 2025 Senior Secured Notes of $66.1 million and a change in fair value of the Martinez Contingent Consideration of $130.7 million. Our results for the nine months ended September 30, 2021 were positively impacted$127.7 million, partially offset by special items consisting of a non-cash lower of cost or market (“LCM”) inventory adjustment of approximately $669.6 million and a gain on the extinguishment of debt associated with the repurchase of a portion of our 2028 Senior Notes and 2025 Senior Notes of $60.3 million, offset by a change in the fair value of the Martinez Contingent Consideration of $23.6$3.8 million.
Excluding the impact of these special items, when comparing our results to the ninesix months ended SeptemberJune 30, 2021,2022, we experienced an increaseoverall decrease in the demand for our refined products, evidenced by higher throughput volumes and barrels sold at all of our refineries, as well as overall stronger refining margins due to favorableunfavorable movements in crack spreads and crude oil differentials. In addition, refined product margins benefited in the prior year from global supply disruptions, caused in large part by the conflict between Russia and Ukraine. These improvingdecreasing metrics have positivelynegatively impacted our revenues, gross margin and operating income.
Revenues— Revenues totaled $35.9$18.4 billion for the ninesix months ended SeptemberJune 30, 20222023 compared to $19.0$23.2 billion for the ninesix months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $16.9$4.8 billion, or 88.9%20.7%. Revenues per barrel were $127.42$98.63 and $76.79$127.97 for the ninesix months ended SeptemberJune 30, 2023 and 2022, and 2021, respectively, an increasea decrease of 65.9%22.9% directly related to higherlower hydrocarbon commodity prices. For the ninesix months ended SeptemberJune 30, 2023, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 315,200 bpd, 126,000 bpd, 169,200 bpd and 283,300 bpd, respectively. For the six months ended June 30, 2022, the total throughput rates at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 291,600277,700 bpd, 152,600149,300 bpd, 185,200181,400 bpd and 291,000279,300 bpd, respectively. For the ninesix months ended SeptemberJune 30, 2021, the2023, total throughput ratesbarrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 250,900365,000 bpd, 138,000139,400 bpd, 158,000178,250 bpd and 276,300349,800 bpd, respectively. For the ninesix months ended SeptemberJune 30, 2022, total barrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 343,600329,200 bpd, 158,500153,700 bpd, 196,300194,900 bpd and 334,900 bpd, respectively. For the nine months ended September 30, 2021, total barrels sold at our East Coast, Mid-Continent, Gulf Coast and West Coast refineries averaged approximately 285,700 bpd, 144,100 bpd, 165,800 bpd and 309,400323,500 bpd, respectively.
Overall theaverage throughput rates were slightly higher in the ninesix months ended SeptemberJune 30, 20222023 compared to the same period in 2021,2022, despite turnaround activity at several refineries during the ninesix months ended SeptemberJune 30, 2022.2023. We plan to continue operating our refineries based on demand and current market conditions. Total refined product barrels sold were higher than throughput rates, reflecting sales from inventory as well as sales and purchases of refined products outside our refineries.
Consolidated Gross Margin— Consolidated gross margin totaled $3,552.6$979.7 million for the ninesix months ended SeptemberJune 30, 2022,2023, compared to $348.9$2,029.7 million for the ninesix months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $3,203.7$1,050.0 million. Gross refining margin (as described below in Non-GAAP Financial Measures) totaled $5,721.0$2,566.0 million, or $22.77$15.86 per barrel of throughput for the ninesix months ended SeptemberJune 30, 20222023 compared to $2,089.0$3,458.9 million, or $9.30$21.54 per barrel of throughput for the ninesix months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $3,632.0$892.9 million. GrossConsolidated gross margin and gross refining margin excluding special items totaled $5,721.0 million or $22.77 per barreldecreased due to unfavorable movements in the crack spreads and crude oil differentials at the majority of throughput forour refineries. During the ninesix months ended SeptemberJune 30, 2022 compared to $1,419.4 million or $6.32 per barrel of throughput for the nine months ended September 30, 2021, an increase of $4,301.6 million.
During the nine months ended September2023 and June 30, 2022, our margin calculations were not impacted by special items. Consolidated gross margin and gross refining margin increased due to favorable movements in certain crack spreads and crude oil differentials and higher throughput volumes and barrels sold at all of our refineries. For the nine months ended September 30, 2021, special items impacting our margin calculations included a non-cash LCM inventory benefit of approximately $669.6 million on a net basis, resulting from an increase in crude oil and refined product prices from the year ended 2020 to the end of the third quarter of 2021.
Additionally, our results continue to be impacted by significant costs to comply with the Renewable Fuel Standard.RFS. Total Renewable Fuel StandardRFS compliance costs were $924.7$470.2 million for the ninesix months ended SeptemberJune 30, 2022 in comparison2023 compared to $653.8$627.1 million for the ninesix months ended SeptemberJune 30, 2021.2022.
Average industry margins were favorableunfavorable during the ninesix months ended SeptemberJune 30, 2022 in comparison2023 compared to the same period in 2021,2022, primarily due to varying timing and extent of the impacts of the COVID-19 pandemic on regional demand and commodity prices, in addition to increaseddecreased refining margins as a result of global supply disruptions.unfavorable movements in the crack spreads and crude oil differentials at the majority of our refineries.
Favorable movements in these benchmark crude differentials typically result in lower crude costs and positively impact our earnings while reductions in these benchmark crude differentials typically result in higher crude costs and negatively impact our earnings.
On the East Coast, the Dated Brent (NYH) 2-1-1 industry crack spread was approximately $38.14$30.09 per barrel, or 137.0% higher,21.8% lower, in the ninesix months ended SeptemberJune 30, 2022,2023, as compared to $16.09$38.47 per barrel in the same period in 2021.2022. Our margins were impacted from our refinery specific slate on the East Coast by strengthened Dated Brent/Maya and WTI/Bakken differentials, which increased by $6.88$5.47 per barrel slightly offset by weakened WTI/Bakken differentials, which decreased by $4.15and $1.41 per barrel, respectively, in comparison to the same period in 2021.2022. The WTI/WCS differential increaseddecreased to $18.74$16.42 per barrel in the ninesix months ended SeptemberJune 30, 20222023 compared to $13.00$16.96 in the same period in 2021,2022, which favorablyunfavorably impacted our cost of heavy Canadian crude.
Across the Mid-Continent, the WTI (Chicago) 4-3-1 industry crack spread was $32.63$28.44 per barrel, or 95.0% higher,9.0% lower, in the ninesix months ended SeptemberJune 30, 20222023 as compared to $16.73$31.24 per barrel in the same period in 2021.2022. Our margins were negativelypositively impacted from our refinery specific slate in the Mid-Continent by a decreasingstrengthened WTI/Bakken differential, andwhich increased by $1.41 per barrel, slightly offset by a weakened WTI/Syncrude differential, which decreased by $4.15$0.96 per barrel, and $5.20 per barrel, respectively.in comparison to the same period in 2022.
On the Gulf Coast, the LLS (Gulf Coast) 2-1-1 industry crack spread was $37.77$30.26 per barrel, or 145.3% higher,18.8% lower, in the ninesix months ended SeptemberJune 30, 20222023 as compared to $15.40$37.27 per barrel in the same period in 2021.2022. Margins on the Gulf Coast were negatively impacted from our refinery specific slate by a weakened WTI/LLS differential, which averaged a premium of $2.08$2.50 per barrel duringfor the ninesix months ended SeptemberJune 30, 20222023 as compared to a premium of $1.63$1.92 per barrel in the same period of 2021.2022.
On the West Coast, the ANS (West Coast) 4-3-1 industry crack spread was $44.45$36.08 per barrel, or 127.0% higher,16.5% lower, in the ninesix months ended SeptemberJune 30, 20222023 as compared to $19.58$43.20 per barrel in the same period in 2021.2022. Additionally (West Coast) 3-2-1 industry crack spread was $44.54$36.36 per barrel, or 131.7% higher,15.0% lower, in the ninesix months ended SeptemberJune 30, 20222023 as compared to $19.22$42.76 per barrel in the same period in 2021.2022. Our margins on the West Coast were negatively impacted from our refinery specific slate by a weakening WTI/ANS differential, which averaged a premium of $3.88$3.87 per barrel duringfor the ninesix months ended SeptemberJune 30, 20222023 as compared to a premium of $2.48$2.16 per barrel in the same period of 2021.2022.
Operating Expenses— Operating expenses totaled $1,829.5$1,320.4 million, or $7.28$8.16 per barrel of throughput, for the ninesix months ended SeptemberJune 30, 20222023 compared to $1,430.1$1,209.4 million, or $6.36$7.53 per barrel of throughput, for the ninesix months ended SeptemberJune 30, 2021,2022, an increase of approximately $399.4$111.0 million, or 27.9%9.2%. The increase in operating expenses was mainly attributable to increases in natural gas volumes and price across our refineries when compared to the same period in 2021. Additionally, we experienced higher outside services, maintenance and operational costs due to scheduled turnarounds and increased production.
General and Administrative Expenses— General and administrative expenses totaled $356.9$157.9 million for the ninesix months ended SeptemberJune 30, 20222023 compared to $150.5$195.2 million for the ninesix months ended SeptemberJune 30, 2021, an increase2022, a decrease of approximately $206.4$37.3 million or 137.1%19.1%. The increase inOur general and administrative expenses for the nine months ended September 30, 2022were lower in comparison to the nine months ended September 30, 2021 primarily relatedprior year due to higherlower employee-related expenses, certain of which includesincluding the recognition of incentive compensation for our non-executive employees. Our generalcompensation. General and administrative expensescosts are comprised of personnel, facilities and other infrastructure costs necessary to support our refineries and related logistics assets.
Loss (Gain) on Sale of Assets— There was a net gain of $1.4 million for the six months ended June 30, 2023 related primarily to the sale of a parcel of land at our Torrance refinery. There was a loss of $0.3 million and a gain of $0.4 million for the ninesix months ended SeptemberJune 30, 2022, and September 30, 2021, respectively, related primarily to the sale of non-operating refinery assets.
Depreciation and Amortization Expense— Depreciation and amortization expense totaled $344.7$270.1 million for the ninesix months ended SeptemberJune 30, 20222023 (including $338.9$265.9 million recorded within Cost of sales) compared to $320.1$223.6 million for the ninesix months ended SeptemberJune 30, 20212022 (including $310.0$219.8 million recorded within Cost of sales), an increase of approximately $24.6$46.5 million. The increase was a result of a general increase in our fixed asset base due to capital projects and turnarounds completed since the thirdsecond quarter of 2021.2022.
Change in Fair Value of Contingent Consideration, net— Change in fair value of contingent consideration represented a gain of $32.9 million and a loss of $130.7$127.7 million for the ninesix months ended SeptemberJune 30, 2023 and June 30, 2022, in comparison to a loss of $23.6 million for the nine months ended September 30, 2021.respectively. These gains and losses were related to the changes in the estimated fair value of the Martinez Contingent Consideration.
Change in Fair Value of Catalyst Obligations— Change in fair value of catalyst obligations represented a lossgain of $0.3$1.2 million for the ninesix months ended SeptemberJune 30, 20222023 compared to a gain of $13.6$2.3 million for the ninesix months ended SeptemberJune 30, 2021.2022. These losses and gains relate to the change in fair value of the precious metals underlying the sale and leaseback of our refineries’ precious metal catalysts, which we are obligated to repurchase at fair market value upon lease termination.
Gain on Extinguishment of Debt— LossThere was no gain or loss on the extinguishment of debt of $66.1 million incurred infor the ninesix months ended SeptemberJune 30, 2022 relates to the redemption of the outstanding 2025 Senior Secured Notes, slightly offset by a gain related to the repurchase of a portion of our 2028 Senior Notes and 2025 Senior Notes, compared to2023. There was a gain on the extinguishment of debt of $60.3$3.8 million incurred in the ninesix months ended SeptemberJune 30, 20212022, related to the repurchase of a portion of our 2028 Senior Notes and 2025 Senior Notes.
Interest Expense, net— Interest expense totaled $186.7$30.0 million for the ninesix months ended SeptemberJune 30, 20222023 compared to $211.0$143.6 million for the ninesix months ended SeptemberJune 30, 2021,2022, a decrease of approximately $24.3$113.6 million. The net decrease is mainly attributedattributable to the redemption of the 2025 Senior Secured Notes during the third quarter of 2022, as well as a lowerno outstanding balance on our Revolving Credit Facility as of SeptemberJune 30, 2022.2023. Additionally, there was a $27.4 million increase in interest income earned during the six months ended June 30, 2023 driven by higher interest rates in comparison to the prior year. Interest expense includes interest on long-term debt, costs related to the sale and leaseback of our precious metal catalysts, financing costs associated with the Third Inventory Intermediation Agreement with J. Aron, which was terminated effective as of July 31, 2023, letter of credit fees associated with the purchase of certain crude oils and the amortization of deferred financing costs.
Income Tax ExpenseBenefit— As PBF Holding is a limited liability company treated as a “flow-through” entity for income tax purposes, our Condensed Consolidated Financial Statements generally do not include a benefit or expense for income taxes for the ninesix months ended SeptemberJune 30, 20222023 and SeptemberJune 30, 2021,2022, respectively, apart from the income tax attributable to two subsidiaries acquired in connection with the acquisition of the Chalmette refinery in the fourth quarter of 2015 and our Canadian subsidiary, PBF Ltd. These subsidiaries are treated as C-Corporations for income tax purposes. An income tax expensebenefit of $1.1$0.6 million was recorded for the ninesix months ended SeptemberJune 30, 20222023 in comparison to an income tax benefit of $16.9$9.3 million recorded for the ninesix months ended SeptemberJune 30, 2021,2022, primarily attributable to the results of PBF Ltd.
Non-GAAP Financial Measures
Management uses certain financial measures to evaluate our operating performance that are calculated and presented on the basis of methodologies other than in accordance with GAAP (“Non-GAAP”). These measures should not be considered a substitute for, or superior to, measures of financial performance prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”), and our calculations thereof may not be comparable to similarly entitled measures reported by other companies.
Special Items
The Non-GAAP measures presented include EBITDA excluding special items and gross refining margin excluding special items. Special items for the periods presented relate to LCM inventory adjustments,net changes in fair value of contingent consideration, and loss (gain)gain on extinguishment of debt.debt and gain on land sale. See “Notes to Non-GAAP Financial Measures” below for more details on all special items disclosed. Although we believe that Non-GAAP financial measures, excluding the impact of special items, provide useful supplemental information to investors regarding the results and performance of our business and allow for helpful period-over-period comparisons, such Non-GAAP measures should only be considered as a supplement to, and not as a substitute for, or superior to, the financial measures prepared in accordance with GAAP.
Gross Refining Margin and Gross Refining Margin Excluding Special Items
Gross refining margin is defined as consolidated gross margin excluding refinery depreciation and operating expenses. We believe both gross refining margin and gross refining margin excluding special items are important measures of operating performance and provide useful information to investors because they are helpful metric comparisons to the industry refining margin benchmarks, as the refining margin benchmarks do not include a charge for refinery operating expenses and depreciation. In order to assess our operating performance, we compare our gross refining margin (revenues less cost of products and other) to industry refining margin benchmarks and crude oil prices as defined in the table below.
Neither gross refining margin nor gross refining margin excluding special items should be considered an alternative to consolidated gross margin, income from operations, net cash flows from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Gross refining margin and gross refining margin excluding special items presented by other companies may not be comparable to our presentation, since each company may define these terms differently.
The following table presents our GAAP calculation of gross margin and a reconciliation of gross refining margin to the most directly comparable GAAP financial measure, consolidated gross margin, on a historical basis, as applicable, for each of the periods indicated (in millions, except per barrel amounts):
| | | Three Months Ended September 30, | | Three Months Ended June 30, |
| | 2022 | | 2021 | | 2023 | | 2022 |
| | $ | | per barrel of throughput | | $ | | per barrel of throughput | | $ | | per barrel of throughput | | $ | | per barrel of throughput |
| Calculation of consolidated gross margin: | Calculation of consolidated gross margin: | | | | | | | | Calculation of consolidated gross margin: | | | | | | | |
| Revenues | Revenues | $ | 12,752.3 | | | $ | 140.77 | | | $ | 7,173.3 | | | $ | 91.92 | | Revenues | $ | 9,148.4 | | | $ | 107.43 | | | $ | 14,064.0 | | | $ | 163.99 | |
| Less: Cost of sales | Less: Cost of sales | 11,229.4 | | | 123.96 | | | 7,056.4 | | | 90.42 | | Less: Cost of sales | 8,692.6 | | | 102.08 | | | 12,180.5 | | | 142.03 | |
| Consolidated gross margin | Consolidated gross margin | $ | 1,522.9 | | | $ | 16.81 | | | $ | 116.9 | | | $ | 1.50 | | Consolidated gross margin | $ | 455.8 | | | $ | 5.35 | | | $ | 1,883.5 | | | $ | 21.96 | |
| Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | | | | | | | | Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | | | | | | | |
| Consolidated gross margin | Consolidated gross margin | $ | 1,522.9 | | | $ | 16.81 | | | $ | 116.9 | | | $ | 1.50 | | Consolidated gross margin | $ | 455.8 | | | $ | 5.35 | | | $ | 1,883.5 | | | $ | 21.96 | |
| Add: Refinery operating expense | Add: Refinery operating expense | 620.1 | | | 6.84 | | | 507.6 | | | 6.50 | | Add: Refinery operating expense | 571.4 | | | 6.71 | | | 613.8 | | | 7.16 | |
| Add: Refinery depreciation expense | Add: Refinery depreciation expense | 119.1 | | | 1.31 | | | 103.0 | | | 1.32 | | Add: Refinery depreciation expense | 133.0 | | | 1.56 | | | 110.9 | | | 1.29 | |
| Gross refining margin | Gross refining margin | $ | 2,262.1 | | | $ | 24.96 | | | $ | 727.5 | | | $ | 9.32 | | Gross refining margin | $ | 1,160.2 | | | $ | 13.62 | | | $ | 2,608.2 | | | $ | 30.41 | |
Special items:(1) | | |
| Add: Non-cash LCM inventory adjustment | — | | | — | | | — | | | — | | |
| | | Gross refining margin excluding special items | Gross refining margin excluding special items | $ | 2,262.1 | | | $ | 24.96 | | | $ | 727.5 | | | $ | 9.32 | | Gross refining margin excluding special items | $ | 1,160.2 | | | $ | 13.62 | | | $ | 2,608.2 | | | $ | 30.41 | |
| | | Nine Months Ended September 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2023 | | 2022 |
| | $ | | per barrel of throughput | | $ | | per barrel of throughput | | $ | | per barrel of throughput | | $ | | per barrel of throughput |
| Calculation of consolidated gross margin: | Calculation of consolidated gross margin: | | | | | | | | Calculation of consolidated gross margin: | | | | | | | |
| Revenues | Revenues | $ | 35,944.5 | | | $ | 143.06 | | | $ | 18,969.7 | | | $ | 84.42 | | Revenues | $ | 18,433.9 | | | $ | 113.96 | | | $ | 23,192.2 | | | $ | 144.35 | |
| Less: Cost of sales | Less: Cost of sales | 32,391.9 | | | 128.92 | | | 18,620.8 | | | 82.86 | | Less: Cost of sales | 17,454.2 | | | 107.90 | | | 21,162.5 | | | 131.71 | |
| Consolidated gross margin | Consolidated gross margin | $ | 3,552.6 | | | $ | 14.14 | | | $ | 348.9 | | | $ | 1.56 | | Consolidated gross margin | $ | 979.7 | | | $ | 6.06 | | | $ | 2,029.7 | | | $ | 12.64 | |
| Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | | | | | | | | Reconciliation of consolidated gross margin to gross refining margin and gross refining margin excluding special items: | | | | | | | |
| Consolidated gross margin | Consolidated gross margin | $ | 3,552.6 | | | $ | 14.14 | | | $ | 348.9 | | | $ | 1.56 | | Consolidated gross margin | $ | 979.7 | | | $ | 6.06 | | | $ | 2,029.7 | | | $ | 12.64 | |
| Add: Refinery operating expense | Add: Refinery operating expense | 1,829.5 | | | 7.28 | | | 1,430.1 | | | 6.36 | | Add: Refinery operating expense | 1,320.4 | | | 8.16 | | | 1,209.4 | | | 7.53 | |
| Add: Refinery depreciation expense | Add: Refinery depreciation expense | 338.9 | | | 1.35 | | | 310.0 | | | 1.38 | | Add: Refinery depreciation expense | 265.9 | | | 1.64 | | | 219.8 | | | 1.37 | |
| Gross refining margin | Gross refining margin | $ | 5,721.0 | | | $ | 22.77 | | | $ | 2,089.0 | | | $ | 9.30 | | Gross refining margin | $ | 2,566.0 | | | $ | 15.86 | | | $ | 3,458.9 | | | $ | 21.54 | |
Special items:(1) | | |
| Add: Non-cash LCM inventory adjustment | — | | | — | | | (669.6) | | | (2.98) | | |
| | Gross refining margin excluding special items | Gross refining margin excluding special items | $ | 5,721.0 | | | $ | 22.77 | | | $ | 1,419.4 | | | $ | 6.32 | | Gross refining margin excluding special items | $ | 2,566.0 | | | $ | 15.86 | | | $ | 3,458.9 | | | $ | 21.54 | |
|
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See Notes to Non-GAAP Financial Measures.
EBITDA, EBITDA Excluding Special Items and Adjusted EBITDA
Our management uses EBITDA (earnings before interest, income taxes, depreciation and amortization), EBITDA excluding special items and Adjusted EBITDA as measures of operating performance to assist in comparing performance from period to period on a consistent basis and to readily view operating trends, as a measure for planning and forecasting overall expectations and for evaluating actual results against such expectations, and in communications with our Board of Directors, creditors, analysts and investors concerning our financial performance. Our outstanding indebtedness for borrowed money and other contractual obligations also include similar measures as a basis for certain covenants under those agreements which may differ from the Adjusted EBITDA definition described below.
EBITDA, EBITDA excluding special items and Adjusted EBITDA are not presentations made in accordance with GAAP and our computation of EBITDA, EBITDA excluding special items and Adjusted EBITDA may vary from others in our industry. In addition, Adjusted EBITDA contains some, but not all, adjustments that are taken into account in the calculation of the components of various covenants in the agreements governing our senior notes and other credit facilities. EBITDA, EBITDA excluding special items and Adjusted EBITDA should not be considered as alternatives to income from operations or net income as measures of operating performance. In addition, EBITDA, EBITDA excluding special items and Adjusted EBITDA are not presented as, and should not be considered, an alternative to cash flows from operations as a measure of liquidity. Adjusted EBITDA is defined as EBITDA before adjustments for items such as stock-based compensation expense, the non-cash change in the fair value of catalyst obligations, the write down of inventory to the LCM, gain on extinguishment of debt,net change in the fair value of contingent consideration and certain other non-cash items. Other companies, including other companies in our industry, may calculate EBITDA, EBITDA excluding special items and Adjusted EBITDA differently than we do, limiting their usefulness as comparative measures. EBITDA, EBITDA excluding special items and Adjusted EBITDA also have limitations as analytical tools and should not be considered in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations include that EBITDA, EBITDA excluding special items and Adjusted EBITDA:
•do not reflect depreciation expense or our cash expenditures, or future requirements, for capital expenditures or contractual commitments;
•do not reflect changes in, or cash requirements for, our working capital needs;
•do not reflect our interest expense, or the cash requirements necessary to service interest or principal payments, on our debt;
•do not reflect realized and unrealized gains and losses from certain hedging activities, which may have a substantial impact on our cash flow;
•do not reflect certain other non-cash income and expenses; and
•exclude income taxes that may represent a reduction in available cash.
The following tables reconcile net income (loss) as reflected in our results of operations to EBITDA, EBITDA excluding special items and Adjusted EBITDA for the periods presented (in millions):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | 2023 | | 2022 |
| | Reconciliation of net income to EBITDA and EBITDA excluding special items: | Reconciliation of net income to EBITDA and EBITDA excluding special items: | | Reconciliation of net income to EBITDA and EBITDA excluding special items: | | | | | | | |
| Net income | Net income | $ | 1,232.4 | | | $ | 64.9 | | | $ | 2,811.3 | | | $ | 50.8 | | Net income | $ | 354.6 | | | $ | 1,596.9 | | | $ | 824.1 | | | $ | 1,578.9 | |
| Add: Depreciation and amortization expense | Add: Depreciation and amortization expense | 121.1 | | | 106.4 | | | 344.7 | | | 320.1 | | Add: Depreciation and amortization expense | 135.3 | | | 112.8 | | | 270.1 | | | 223.6 | |
| Add: Interest expense, net | Add: Interest expense, net | 43.1 | | | 71.5 | | | 186.7 | | | 211.0 | | Add: Interest expense, net | 15.1 | | | 75.4 | | | 30.0 | | | 143.6 | |
| Add: Income tax expense (benefit) | 10.4 | | | (2.0) | | | 1.1 | | | (16.9) | | |
| Add: Income tax benefit | | Add: Income tax benefit | — | | | (1.2) | | | (0.6) | | | (9.3) | |
| EBITDA | EBITDA | $ | 1,407.0 | | | $ | 240.8 | | | $ | 3,343.8 | | | $ | 565.0 | | EBITDA | $ | 505.0 | | | $ | 1,783.9 | | | $ | 1,123.6 | | | $ | 1,936.8 | |
Special Items:(1) | Special Items:(1) | | Special Items:(1) | |
| Add: Non-cash LCM inventory adjustment | — | | | — | | | — | | | (669.6) | | |
| Add: Change in fair value of contingent consideration | 3.0 | | | (0.7) | | | 130.7 | | | 23.6 | | |
| | Add: Change in fair value of contingent consideration, net | | Add: Change in fair value of contingent consideration, net | (16.6) | | | 77.6 | | | (32.9) | | | 127.7 | |
| Add: Gain on land sales | | Add: Gain on land sales | — | | | — | | | (1.7) | | | — | |
| | Add: Loss (gain) on extinguishment of debt | 69.9 | | | (60.3) | | | 66.1 | | | (60.3) | | |
| | Add: Gain on extinguishment of debt | | Add: Gain on extinguishment of debt | — | | | (3.8) | | | — | | | (3.8) | |
| EBITDA excluding special items | EBITDA excluding special items | $ | 1,479.9 | | | $ | 179.8 | | | $ | 3,540.6 | | | $ | (141.3) | | EBITDA excluding special items | $ | 488.4 | | | $ | 1,857.7 | | | $ | 1,089.0 | | | $ | 2,060.7 | |
| | Reconciliation of EBITDA to Adjusted EBITDA: | Reconciliation of EBITDA to Adjusted EBITDA: | | Reconciliation of EBITDA to Adjusted EBITDA: | |
| EBITDA | EBITDA | $ | 1,407.0 | | | $ | 240.8 | | | $ | 3,343.8 | | | $ | 565.0 | | EBITDA | $ | 505.0 | | | $ | 1,783.9 | | | $ | 1,123.6 | | | $ | 1,936.8 | |
| Add: Stock-based compensation | Add: Stock-based compensation | 6.2 | | | 6.1 | | | 20.7 | | | 20.1 | | Add: Stock-based compensation | 9.7 | | | 7.4 | | | 18.9 | | | 14.5 | |
| Add: Change in fair value of catalyst obligations | Add: Change in fair value of catalyst obligations | 2.6 | | | (17.8) | | | 0.3 | | | (13.6) | | Add: Change in fair value of catalyst obligations | (0.5) | | | (7.2) | | | (1.2) | | | (2.3) | |
Add: Non-cash LCM inventory adjustment (1) | — | | | — | | | — | | | (669.6) | | |
Add: Change in fair value of contingent consideration (1) | 3.0 | | | (0.7) | | | 130.7 | | | 23.6 | | |
| Add: Change in fair value of contingent consideration, net (1) | | Add: Change in fair value of contingent consideration, net (1) | (16.6) | | | 77.6 | | | (32.9) | | | 127.7 | |
Add: Gain on land sales(1) | | Add: Gain on land sales(1) | — | | | — | | | (1.7) | | | — | |
| Add: Loss (gain) on extinguishment of debt (1) | 69.9 | | | (60.3) | | | 66.1 | | | (60.3) | | |
Add: Gain on extinguishment of debt (1) | | Add: Gain on extinguishment of debt (1) | — | | | (3.8) | | | — | | | (3.8) | |
| Adjusted EBITDA | Adjusted EBITDA | $ | 1,488.7 | | | $ | 168.1 | | | $ | 3,561.6 | | | $ | (134.8) | | Adjusted EBITDA | $ | 497.6 | | | $ | 1,857.9 | | | $ | 1,106.7 | | | $ | 2,072.9 | |
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See Notes to Non-GAAP Financial Measures.
Notes to Non-GAAP Financial Measures
The following notes are applicable to the Non-GAAP Financial Measures above:
(1) Special items:
LCM inventory adjustment - LCM is a GAAP requirement related to inventory valuation that mandates inventory to be stated at the lower of cost or market. Our inventories are stated at the lower of cost or market. Cost is determined using the last-in, first-out (“LIFO”) inventory valuation methodology,Change in which the most recently incurred costs are charged to cost of sales and inventories are valued at base layer acquisition costs. Market is determined based on an assessment of the current estimated replacement cost and net realizable selling price of the inventory. In periods where the market price of our inventory declines substantially, cost values of inventory may exceed market values. In such instances, we record an adjustment to write down thefair value of inventory to market value in accordance with GAAP. In subsequent periods, the value of inventory is reassessed and an LCM inventory adjustment is recorded to reflect thecontingent consideration, net change in the LCM inventory reserve between the prior period and the current period. The net impact of these LCM inventory adjustments are included in income from operations, but are excluded from the operating results presented, as applicable, in order to make such information comparable between periods.
The following table includes the LCM inventory reserve as of each date presented (in millions):
| | | | | | | | | | | |
| 2022 | | 2021 |
| January 1, | $ | — | | | $ | 669.6 | |
| | | |
| June 30, | — | | | — | |
| September 30, | — | | | — | |
The following table includes the corresponding impact of changes in the LCM inventory reserve on both income from operations and net income for the periods presented (in millions):
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended September 30, | | Nine Months Ended September 30, |
| |
| 2022 | | 2021 | | 2022 | | 2021 |
| Net LCM inventory adjustment benefit in both income from operations and net income | $ | — | | | $ | — | | | $ | — | | | $ | 669.6 | |
Change in Fair Value of Contingent Consideration - During the three months ended SeptemberJune 30, 2023, we recorded a change in fair value of the Martinez Contingent Consideration which increased income from operations and net income by $16.6 million. During the six months ended June 30, 2023, we recorded a change in fair value of the Martinez Contingent Consideration which increased income from operations and net income by $32.9 million. During the three months ended June 30, 2022, we recorded a change in fair value of the Martinez Contingent Consideration which decreased income from operations and net income by $3.0$77.6 million. During the ninesix months ended SeptemberJune 30, 2022, we recorded a change in fair value of the Martinez Contingent Consideration which decreased income from operations and net income by $130.7$127.7 million. During the three months ended September 30, 2021, we recorded a change in fair value of the Martinez Contingent Consideration which increased income from operations and net income by $0.7 million. During the nine months ended September 30, 2021, we recorded a change in fair value of the Martinez Contingent Consideration which decreased income from operations and net income by $23.6 million.
Loss (Gain)Gain on Extinguishmentextinguishment of Debtdebt - During the three and six months ended SeptemberJune 30, 2022, we recorded a loss on extinguishment of debt related to the redemption of our 2025 Senior Secured Notes which decreased income before income taxes and net income by $69.9 million. During the nine months ended September 30, 2022, we recorded a loss on extinguishment of debt which decreased income before income taxes and net income by $66.1 million, primarily related to the redemption of our 2025 Senior Secured Notes, partially offset by the repurchase of a portion of the 2028 Senior Notes and the 2025 Senior Notes. During the three and nine months ended September 30, 2021, we recorded apre-tax gain on extinguishment of debt related to the repurchase of a portion of the 2028 Senior Notes and the 2025 Senior Notes, which increased income before income taxes and net income by $60.3$3.8 million. There were no such gains during the three and six months ended June 30, 2023.
Gain on land sales - During the six months ended June 30, 2023, we recorded a gain on the sale of a separate parcel of real property acquired as part of the Torrance refinery, but not part of the refinery itself, which increased income from operations and net income by $1.7 million. There was no such gain in any other periods presented.
Liquidity and Capital Resources
Overview
Our primary sources of liquidity are our cash flows from operations, cash and cash equivalents and borrowing availability under our credit facility, as described below. We believe that our cash flows from operations and available capital resources will be sufficient to meet our and our subsidiaries’ capital expenditures, working capital needs, future distributions and debt service requirements, for the next twelve months. However, our ability to generate sufficient cash flow from operations depends, in part, on petroleum oil market pricing and general economic, political and other factors beyond our control. As of SeptemberJune 30, 2022,2023, we are in compliance with all covenants, including financial covenants, in all our debt agreements.
Cash Flow Analysis
Cash Flows from Operating Activities
Net cash provided by operating activities was $3,531.3$598.9 million for the ninesix months ended SeptemberJune 30, 20222023 compared to net cash provided by operating activities of $184.9$2,156.2 million for the ninesix months ended SeptemberJune 30, 2021.2022. Our operating cash flows for the ninesix months ended SeptemberJune 30, 20222023 include our net income of $2,811.3$824.1 million, depreciation and amortization of $360.0$280.7 million, pension and other post-retirement benefits costs of $23.9 million, stock-based compensation of $18.9 million, net non-cash charges related to the change in the fair value of our inventory repurchase obligations of $8.5 million, deferred income taxes of $0.1 million, partially offset by a net change in the fair value of the Martinez Contingent Consideration of $130.7$32.9 million, gain on sale of assets of $1.4 million and a change in the fair value of our catalyst obligations of $1.2 million. In addition, net changes in operating assets and liabilities reflected uses of cash of $521.8 million, driven by the timing of inventory purchases, payments for accrued expenses and accounts payable, and collections of accounts receivable. The change in accrued expenses was due primarily to a decrease in renewable energy credit and emissions obligations, as a result of a decrease in our unfunded RINs obligation. Our operating cash flows for the six months ended June 30, 2022 included net income of $1,578.9 million and net changes in operating assets and liabilities reflecting cash proceeds of $126.6$196.3 million, driven by the timing of inventory purchases, payments for accrued expenses and accounts payable, and collections of accounts receivable. Change in accrued expenses iswas due primarily to an increase in renewable energy credit and emissions obligations, as a result of an increase in our unfunded RINs obligation as of SeptemberJune 30, 2022. Our overall increase in cash provided by operating activities also included a loss on extinguishmentdepreciation and amortization of debt primarily related to$233.5 million, change in fair value of the redemptionMartinez Contingent Consideration of our 2025 Senior Secured Notes of $66.1$127.7 million, pension and other post-retirement benefits costs of $35.7$23.8 million, stock-based compensation of $20.7 million, deferred income taxes of $0.7 million, change in the fair value of our catalyst obligations of $0.3$14.5 million, and loss on sale of assets of $0.3 million, partially offset by net non-cash charges related to the change in the fair valuedeferred incomes taxes of our inventory repurchase obligations of $21.1 million. Our operating cash flows for the nine months ended September 30, 2021 included our net income of $50.8$9.3 million, net changes in operating assets and liabilities reflecting cash proceeds of $434.5 million, depreciation and amortization of $331.4 million, net non-cash charges related to the change in fair value of our inventory repurchase obligations of $46.0 million, pension and other post-retirement benefits costs of $38.0 million, change in the fair value of the Martinez Contingent Consideration of $23.6 million, and stock-based compensation of $20.1 million, partially offset by a non-cash benefit of $669.6 million relating to an LCM inventory adjustment, gain on extinguishment of debt related to the repurchase of a portion of our 2028 Senior Notes and 2025 Senior Notes of $60.3$3.8 million, deferred income taxesnet non-cash charges related to changes in fair value of $15.6our inventory repurchase obligations of $3.4 million and change in the fair value of our catalyst obligations of $13.6 million and gain on sale of assets of $0.4$2.3 million.
Cash Flows from Investing Activities
Net cash used in investing activities was $679.1$740.6 million for the ninesix months ended SeptemberJune 30, 20222023 compared to net cash used in investing activities of $220.3$433.8 million for the ninesix months ended SeptemberJune 30, 2021.2022. The net cash flows used in investing activities for the ninesix months ended SeptemberJune 30, 2023 was comprised of cash outflows of capital expenditures totaling $442.0 million, expenditures for refinery turnarounds of $268.0 million, and expenditures for other assets of $35.0 million, partially offset by proceeds from the sale of assets of $4.4 million. The net cash used in investing activities for the six months ended June 30, 2022 was comprised of cash outflows of capital expenditures totaling $386.9$223.4 million, expenditures for refinery turnarounds of $240.3$166.8 million, and expenditures for other assets of $51.9$43.6 million. The net cash used in investing activities for the nine months ended September 30, 2021 was comprised of cash outflows of capital expenditures totaling $135.1 million, expenditures for refinery turnarounds of $64.6 million, and expenditures for other assets of $20.6 million.
Cash Flows from Financing Activities
Net cash used in financing activities was $2,306.4$515.4 million for the ninesix months ended SeptemberJune 30, 20222023 compared to net cash used in financing activities of $92.9$918.0 million for the ninesix months ended SeptemberJune 30, 2021.2022. For the ninesix months ended SeptemberJune 30, 2023, net cash used in financing activities consisted primarily of distributions to members of $1,099.0 million, payments related to the Martinez Contingent Consideration of $80.1 million, payments on finance leases of $5.8 million, and deferred financing costs and other of $0.5 million, partially offset by proceeds from contributions from PBF LLC of $635.0 million and proceeds from insurance premium financing of $35.0 million. For the six months ended June 30, 2022, net cash used in financing activities consisted primarily of the redemption of our 2025 Senior Secured notes of $1,307.4 million, net repayments on the Revolving Credit Facility of $900.0 million, distributions to members of $56.6 million, settlement of precious metal catalyst obligations of $37.3 million, deferred financing costs and other of $31.2 million, $25.9 million related to the repurchase of the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, and payments on finance leasesdistributions to members of $8.5 million, partially offset by proceeds from contributions from PBF LLC of $50.0 million, and proceeds from insurance premium financing of $10.5 million. For the nine months ended September 30, 2021, net cash used in financing activities consisted primarily of $90.9 million related to the repurchase of the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, net settlements of precious metal catalyst obligations of $18.5$11.6 million, payments on finance leases of $10.7 million, principal amortization payments of the $35.0 million PBF Rail term loan of $5.5 million, and distributions to members of $2.7 million, partially offset by proceeds from contributions from PBF LLC of $28.0 million, proceeds from insurance premium financing of $7.0$5.7 million, and deferred financing costs and other of $0.4 million.
Debt and Credit Facility
Long-Term Debt Related Transactions
During the three and nine months ended September 30, 2022, we exercised our rights under the indenture governing the 2025 Senior Secured Notes to redeem all$32.2 million, partially offset by proceeds from insurance premium financing of the outstanding 2025 Senior Secured Notes at a price of 104.625% of the aggregate principal amount thereof plus accrued and unpaid interest. The aggregate redemption price for all 2025 Senior Secured Notes approximated $1.3 billion plus accrued and unpaid interest. The difference between the carrying value of the 2025 Senior Secured Notes on the date they were redeemed and the amount for which they were redeemed was $69.9$32.4 million, and was recorded as a loss on extinguishmentproceeds from contributions from PBF LLC of debt in the Consolidated Statements of Operations.
During the nine months ended September 30, 2022, we made a number of open market repurchases of our 2028 Senior Notes and 2025 Senior Notes that resulted in the extinguishment of $24.9 million in principal of the 2028 Senior Notes and $5.0 million in principal of the 2025 Senior Notes. Total cash consideration paid to repurchase the principal amount outstanding of the 2028 Senior Notes and the 2025 Senior Notes, excluding accrued interest, totaled $25.9 million and we recognized a $3.8 million gain on the extinguishment of debt during the nine months ended September 30, 2022.
Revolving Credit Facility
On May 25, 2022, we entered into an amendment of our Revolving Credit Agreement. Among other things, the Revolving Credit Agreement amended and extended the Revolving Credit Facility through January 2025 and increased the maximum commitment to $4.3 billion through May 2023 (currently set to adjust to $2.75 billion in May 2023 through January 2025). The amendments also redefine certain components of the Borrowing Base (as defined in the Revolving credit Agreement) to reflect the existence of the two tranches, Tranche A Commitments and Tranche B Commitments. The Tranche A Commitments total $1.55 billion and the Tranche B Commitments total $2.75 billion. The amendments also include changes to incorporate the adoption of SOFR as a replacement of LIBOR, changes to joint lead arrangers, bookrunners, syndication agents and other titles, and other changes related to the foregoing. In addition, an accordion feature allows for additional Tranche B Commitments of up to an additional $500.0 million plus an amount equal to the Tranche A Commitments for existing Tranche A lenders.
Catalyst Financing Obligations
During the three months ended September 30, 2022, we settled certain of our precious metals financing arrangements, which represented a reduction of debt of approximately $37.3$25.0 million.
Liquidity
As of SeptemberJune 30, 2022,2023, our operational liquidity was more than $4.4$3.7 billion which consists of $1.8$1.5 billion of cash, and more than $2.6$2.2 billion of borrowing availability under our Revolving Credit Facility, which includes our cash on hand.
As of SeptemberJune 30, 2022,2023, outstanding letters of credit totaled approximately $815.9$287.0 million.
We have executed a plan to strengthen our balance sheet and increase our flexibility and responsiveness by incorporating certain adjustments to our corporate structure, operations and other cost saving measures. In an effort to preserve the positive recovery trends experienced since the beginning of 2021, we remain committed to our plan with notable events within the past twelve months highlighted below:
•July 2022 full redemption of our 2025 Senior Secured Notes using cash on hand as of June 30, 2022, resulting in annual interest savings of approximately $115.0 million;
•Extinguishment of $258.9 million of our 2028 Senior Notes and 2025 Senior Notes to date, resulting in annual cash interest savings of approximately $16.3 million;
•In May 2022, completed a multi-year extension of our Revolving Credit Facility, with an aggregate commitment of $4.3 billion; and
•In October 2021, executed the Third Inventory Intermediation Agreement with J. Aron through 2024, covering certain crude oil, intermediate and finished products across our East Coast and Chalmette refineries.
We are actively responding tomonitoring the ongoing rebalancingvolatility in the global oil markets. Wemarkets and we continue to adjust our operational plans to the evolving market conditions and continue to target and execute expense reduction measures. We also remain committed to assessing other opportunities that could improve our liquidity, including by further reducing debt and/or potential sales of non-operating assets or other real property, although there can be no assurance that we will do so. conditions.
We may, at any time and from time to time, seek to continue to repurchase or retire our outstanding debt securities through cash purchases (and/or exchanges for equity or debt), in open-market purchases, block trades, privately negotiated transactions or otherwise, upon such terms and at such prices as we may determine. We will evaluate any such transactions in light of then-existing market conditions, taking into account our current liquidity and prospects for future access to capital, the trading prices of our debt securities, legal requirements and contractual restrictions and economic and market conditions. The amounts involved in any such transactions, individually or in the aggregate, may be material. We are not obligated to repurchase any of our debt securities other than as set forth in the applicable indentures, and repurchases may be made or suspended orif made, discontinued at any time without prior notice.
We may incur additional indebtedness in the future, including additional secured indebtedness, subject to the satisfaction of any debt incurrence and, if applicable, lien incurrence limitation covenants in our existing financing agreements. Although we were in compliance with incurrence covenants during the nine months ended September 30, 2022, to the extent that any of our activities triggered these covenants, there are no assurances that conditions could not change significantly, and that such changes could adversely impact our ability to meet some of these incurrence covenants at the time that we needed to. Failure to meet the incurrence covenants could impose certain incremental restrictions on, among other matters, our ability to incur new debt (including secured debt) and also may limit the extent to which we may pay future dividends, make new investments, repurchase our outstanding debt or stock or incur new liens.
Working Capital
Our working capital at SeptemberJune 30, 20222023 was $1,593.3$1,538.1 million, consisting of $6,510.9$5,847.8 million in total current assets and $4,917.6$4,309.7 million in total current liabilities. Our working capital at December 31, 20212022 was $1,266.5$1,715.3 million, consisting of $5,158.6$6,494.5 million in total current assets and $3,892.1$4,779.2 million in total current liabilities.
Capital Spending
Capital spending was $679.1$745.0 million for the ninesix months ended SeptemberJune 30, 20222023 and was primarily comprised of annual maintenance, turnaround costs at our Delaware City, Toledo, Chalmette, Torrance and Martinez refineries and spending related to ourthe Renewable Diesel Project at the Chalmette refinery.Facility. Capital spendspending also included costs associated with safety related enhancements and facility improvements at our refineries. Excluding capital expenditures related to our Renewable Diesel Project, ourFacility, we currently expect to spend an aggregate of approximately $750.0 million during full-year refining capital2023 for facility improvements and refinery maintenance and turnarounds, as well as expenditures are expected to range from $550.0 million to $575.0 million, which includes advanced purchases of materials for future turnarounds.
During the third quarter of 2022, we also invested approximately $103.0 million in capital to progressmeet environmental, regulatory and incubate our Renewable Diesel Project with the goal of being in production in the first half of 2023.safety requirements.
Construction of the Renewable Diesel Facility was substantially completed as of June 30, 2023. During the second quarter of 2023, we invested approximately $107.4 million in capital related to the project. The remaining capital expenditures to complete the project are not expected to be material.
Crude and Feedstock Supply Agreements
Certain of our purchases of crude oil under our agreements with foreign national oil companies require that we post letters of credit, if open terms are exceeded, and arrange for shipment. We pay for the crude when invoiced, at which time any applicable letters of credit are lifted. We have a contract with Saudi Arabian Oil Company (“Saudi Aramco”) pursuant to which we have been purchasing up to approximately 100,000 bpd of crude oil from Saudi Aramco that is processed at our Paulsboro refinery. In connection with the acquisition of the Chalmette refinery we entered into a contract with Petróleos de Venezuela S.A. (“PDVSA”) for the supply of 40,000 to 60,000 bpd of crude oil that can be processed at any of our East or Gulf Coast refineries. We have not sourced crude oil under this agreement since 2017 when PDVSA suspended deliveries due to the parties’ inability to agree to mutually acceptable payment terms and because of U.S. government sanctions against PDVSA. Notwithstanding the suspension, the U.S. government sanctions imposed against PDVSA and Venezuela prevented us from purchasing crude oil under this agreement. In connection with the closing of the acquisition of the Torrance refinery, we entered into a crude supply agreement with Exxon Mobil Oil Corporation (“ExxonMobil”) for approximately 60,000 bpd of crude oil that can be processed at our Torrance refinery. We currently purchase all of our crude and feedstock needs independently from a variety of suppliers on the spot market or through term agreements for our Delaware City and Toledo refineries.
We As part of our term agreements, we currently have various crude supply agreements with terms through 2025 with Shell plcOil Products for approximately 145,000 bpd, in the aggregate, to support our West Coast and Mid-Continent refinery operations. In addition, we have certain offtake agreements for our West Coast system with the same counterparty for clean products with varying terms up to 15 years.terms.
Inventory Intermediation Agreement
On October 25, 2021, PBF Holding and its subsidiaries,We entered into the Third Inventory Intermediation Agreement with J. Aron, to support the operations of Delaware City Refining Company LLC (“DCR”), Paulsboro Refining Company LLC (“PRC”) and Chalmette Refining, L.L.CL.L.C. (“Chalmette Refining”) (collectively, the “PBF Entities”), entered into the Third Inventory Intermediation Agreement with J. Aron, pursuant to which the terms of the previous inventory intermediation agreements were amended and restated in their entirety, including, among other things, pricing and an extension of terms.. The Third Inventory Intermediation Agreement extends the termwas set to expire on December 31, 2024, which term may becould have been further extended by mutual consent of the parties to December 31, 2025. If not extended or replaced, at expiration, we will be required to repurchase the inventories outstanding under the Third Inventory Intermediation Agreement at that time. On May 25, 2022,However, on June 28, 2023, the PBF Entities entered into ana second amendment of the Third Inventory Intermediation Agreement to amend certain provisions thereof that relatedin order to and were impactedallow for the early termination of the Third Inventory Intermediation Agreement effective as of July 31, 2023. Following the early termination, we own all of the inventory previously held by amendments made on May 25, 2022 to the Revolving Credit Agreement.J. Aron.
At SeptemberJune 30, 2022,2023, the LIFOlast-in, first-out (“LIFO”) carrying value of the products owned by J. Aron Productsunder the Third Inventory Intermediation Agreement included within InventoryInventories in our Condensed Consolidated Balance Sheets was $384.1$234.1 million. We accrue a corresponding liability for such crude oil, intermediates and finished products.
Distributions
We make, from time to time, distributions to PBF LLC, if necessary, in order for PBF LLC to make pro rata distributions to its members, including PBF Energy, necessary to fund in excess of one year’s cash dividend payments by PBF Energy.
On October 27, 2022,August 3, 2023, PBF Energy, our indirect parent, announced a dividend of $0.20 per share on its outstanding Class A common stock. The dividend is payable on November 29, 2022August 31, 2023 to PBF Energy Class A common stockholders of record at the close of business on November 14, 2022.August 17, 2023. If necessary, we will make a distribution of up to approximately $24.6$25.0 million to PBF LLC, which in turn will make pro-rata distributions of $0.20 per unit to its members, including PBF Energy. PBF Energy will then use this distribution to fund the dividend payments to the stockholders of PBF Energy.
In cases when there is sufficient cash and cash equivalents and borrowing capacity, we are permitted under our debt agreements to make these distributions; however, our ability to continue to comply with our debt covenants is, to a significant degree, subject to our operating results, which are dependent on a number of factors outside of our control.
Supplemental Guarantor Financial Information
As of SeptemberJune 30, 2022,2023, PBF Services Company LLC, DCR, PBF Power Marketing LLC, PRC, Toledo Refining Company LLC, Chalmette Refining, PBF Western Region LLC, Torrance Refining Company LLC (“Torrance Refining”), Martinez Refining Company LLC (“MRC”), PBF International Inc. and PBF Investments LLC are 100% owned subsidiaries of PBF Holding and serve as guarantors of the obligations under the 2025 Senior Notes and the 2028 Senior Notes. These guarantees are full and unconditional and joint and several. PBF Holding serves as the “Issuer”. The indentures dated May 30, 2017 and January 24, 2020, among PBF Holding, PBF Finance, the guarantors party thereto, Wilmington Trust, National Association, as trustee and Deutsche Bank Trust Company Americans, as Paying Agent, Registrar, Transfer Agent and Authenticating Agent, govern subsidiaries designated as “Guarantor Subsidiaries”. PBF Ltd, PBF Transportation Company LLC, PBF Rail Logistics Company LLC, MOEM Pipeline LLC, Collins Pipeline Company, T&M Terminal Company, Torrance Basin Pipeline Company LLC, Torrance Logistics Company LLC, Torrance Pipeline Company LLC, Martinez Terminal Company LLC, Martinez Pipeline Company LLC and PBFWR Logistics Holdings LLC are consolidated subsidiaries of the Company that are not guarantors of the 2025 Senior Notes and 2028 Senior Notes. The 2025 Senior Notes and 2028 Senior Notes were co-issued by PBF Finance. For purposes of the following information, PBF Finance is referred to as “Co-Issuer.” The Co-Issuer has no independent assets or operations.
The following tables present summarized information for the Issuer and the Guarantor Subsidiaries on a combined basis after elimination of (i) intercompany transactions and balances among the Issuer and the Guarantor Subsidiaries and (ii) equity in earnings from and investments in any subsidiary that is a non-guarantor.
| | | | | | | | | | | |
| Summarized Balance Sheets (in millions) | September 30,
2022 | | December 31,
2021 |
| ASSETS | | | |
Current Assets (1) | $ | 6,240.3 | | | $ | 4,840.0 | |
| Non-Current Assets | 6,003.5 | | | 5,754.0 | |
| Due from non-guarantor subsidiaries | 18,727.9 | | | 16,211.0 | |
| | | |
| LIABILITIES AND EQUITY | | | |
Current liabilities (1) | $ | 4,649.1 | | | $ | 3,645.0 | |
| Long-term liabilities | 2,610.1 | | | 4,862.0 | |
| Due to non-guarantor subsidiaries | 18,693.2 | | | 16,100.0 | |
| | | |
(1) Includes $4.5 million and $41.0 million of accounts receivable and accounts payable, respectively, related to transactions with PBFX as of September 30, 2022. Includes $4.1 million and $61.7 million of accounts receivable and accounts payable, respectively, related to transactions with PBFX as of December 31, 2021. Refer to “Note 6 - Related Party Transactions” of our Notes to Condensed Consolidated Financial Statements for further information. |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended September 30, | Nine Months Ended September 30, |
| Summarized Statements of Operations (in millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Revenues | $ | 12,692.4 | | | $ | 7,067.9 | | | $ | 35,655.0 | | | $ | 18,758.9 | |
| Cost of sales | 10,389.3 | | | 6,375.2 | | | 29,640.8 | | | 16,762.2 | |
| Gross margin | 2,303.1 | | | 692.7 | | | 6,014.2 | | | 1,996.7 | |
| Income from operations | 2,135.5 | | | 633.9 | | | 5,520.2 | | | 1,815.3 | |
| | | | | | | |
| Net income | 2,083.6 | | | 636.5 | | | 5,269.9 | | | 1,632.3 | |
| Net income attributable to PBF Holding Company LLC | 2,083.3 | | | 635.6 | | | 5,271.3 | | | 1,629.0 | |
| | | | | | | |
| Non-guarantor intercompany sales with the Issuer and Guarantor subsidiaries | $ | 869.3 | | | $ | 594.9 | | | $ | 2,545.4 | | | $ | 1,637.6 | |
| Non-guarantor intercompany cost of sales with the Issuer and Guarantor subsidiaries | 18.0 | | | 24.1 | | | 86.8 | | | 56.9 | |
Affiliate revenues related to transactions with PBFX (1) | 4.3 | | | 4.0 | | | 12.7 | | | 12.0 | |
Affiliate expenses related to transactions with PBFX (1) | 77.4 | | | 75.5 | | | 233.0 | | | 226.5 | |
(1) Refer to “Note 6 - Related Party Transactions” of our Notes to Condensed Consolidated Financial Statements for further information. |
| | | | | | | | | | | |
| Summarized Balance Sheets (in millions) | June 30,
2023 | | December 31,
2022 |
| ASSETS | | | |
Current assets (1) | $ | 5,638.0 | | | $ | 6,252.0 | |
| Non-current assets | 5,943.0 | | | 6,283.0 | |
| Due from non-guarantor subsidiaries | 20,486.0 | | | 19,487.0 | |
| | | |
| LIABILITIES AND EQUITY | | | |
Current liabilities (1) | $ | 4,089.0 | | | $ | 4,569.0 | |
| Long-term liabilities | 2,584.0 | | | 2,634.0 | |
| Due to non-guarantor subsidiaries | 20,430.0 | | | 19,394.0 | |
| | | |
| (1) Includes $16.0 million and $38.5 million of accounts receivable and accounts payable, respectively, related to transactions with PBFX as of June 30, 2023. Includes $6.3 million and $38.2 million of accounts receivable and accounts payable, respectively, related to transactions with PBFX as of December 31, 2022. Refer to “Note 6 - Related Party Transactions” of our Notes to Condensed Consolidated Financial Statements for further information. |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, | Six Months Ended June 30, |
| Summarized Statements of Operations (in millions) | 2023 | | 2022 | | 2023 | | 2022 |
| Revenues | $ | 9,067.9 | | | $ | 13,938.7 | | | $ | 18,259.5 | | | $ | 22,962.6 | |
| Cost of sales | 8,050.1 | | | 11,139.7 | | | 16,297.4 | | | 19,251.5 | |
| Gross margin | 1,017.8 | | | 2,799.0 | | | 1,962.1 | | | 3,711.1 | |
| Income from operations | 931.5 | | | 2,573.6 | | | 1,835.2 | | | 3,384.7 | |
| | | | | | | |
| Net income | 912.9 | | | 2,495.2 | | | 1,802.3 | | | 3,186.3 | |
| Net income attributable to PBF Holding Company LLC | 912.7 | | | 2,495.8 | | | 1,801.9 | | | 3,188.0 | |
| | | | | | | |
| Non-guarantor intercompany sales with the Issuer and Guarantor subsidiaries | $ | 568.9 | | | $ | 940.0 | | | $ | 991.1 | | | $ | 1,676.1 | |
| Non-guarantor intercompany cost of sales with the Issuer and Guarantor subsidiaries | 10.6 | | | 41.8 | | | 12.9 | | | 68.8 | |
Affiliate revenues related to transactions with PBFX (1) | 4.2 | | | 4.4 | | | 8.2 | | | 8.4 | |
Affiliate expenses related to transactions with PBFX (1) | 84.8 | | | 79.6 | | | 173.8 | | | 155.6 | |
| (1) Refer to “Note 6 - Related Party Transactions” of our Notes to Condensed Consolidated Financial Statements for further information. |
Item 3. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to market risks, including changes in commodity prices and interest rates. Our primary commodity price risk is associated with the difference between the prices we sell our refined products and the prices we pay for crude oil and other feedstocks. We may use derivative instruments to manage the risks from changes in the prices of crude oil and refined products, natural gas, interest rates, or to capture market opportunities.
Commodity Price Risk
Our earnings, cash flow and liquidity are significantly affected by a variety of factors beyond our control, including the supply of, and demand for, crude oil, other feedstocks, refined products and natural gas. The supply of and demand for these commodities depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, planned and unplanned downtime in refineries, pipelines and production facilities, production levels, the availability of imports, the marketing of competitive and alternative fuels, and the extent of government regulation. As a result, the prices of these commodities can be volatile. Our revenues fluctuate significantly with movements in industry refined product prices, our cost of sales fluctuates significantly with movements in crude oil and feedstock prices and our operating expenses fluctuate with movements in the price of natural gas. We manage our exposure to these commodity price risks through our supply and offtake agreements as well as through the use of various commodity derivative instruments.
We may use non-trading derivative instruments to manage exposure to commodity price risks associated with the purchase or sale of crude oil and feedstocks, finished products and natural gas outside of our supply and offtake agreements. The derivative instruments we use include physical commodity contracts and exchange-traded and over-the-counter financial instruments. We mark-to-market our commodity derivative instruments and recognize the changes in their fair value in our statements of operations.
At SeptemberJune 30, 20222023 and December 31, 2021,2022, we had gross open commodity derivative contracts representing 70.029.4 million barrels and 42.130.1 million barrels, respectively, with an unrealized net gain of $20.2$16.6 million and unrealized net lossgain of $12.0$13.9 million, respectively. The open commodity derivative contracts as of SeptemberJune 30, 20222023 expire at various times during 20222023 and 2023.2024.
We carry inventories of crude oil, intermediates and refined products (“hydrocarbon inventories”) on our Condensed Consolidated Balance Sheets, the values of which are subject to fluctuations in market prices. Our hydrocarbon inventories totaled approximately 32.433.5 million barrels and 30.232.8 million barrels at SeptemberJune 30, 20222023 and December 31, 2021,2022, respectively. The average cost of our hydrocarbon inventories was approximately $78.56$80.18 and $78.29$80.04 per barrel on a LIFO basis at SeptemberJune 30, 20222023 and December 31, 2021,2022, respectively. At SeptemberJune 30, 20222023 and December 31, 2021,2022, the replacement value of inventory exceeded the LIFO carrying value. If market prices of our inventory decline to a level below our average cost, we may be required to write down the carrying value of our hydrocarbon inventories to market.
Our predominant variable operating cost is energy, which is comprised primarily of natural gas and electricity. We are therefore sensitive to movements in natural gas prices. Assuming normal operating conditions, we expect our annual consumption to range from 75 million to 95 million MMBTUs of natural gas amongst our six refineries. Accordingly, a $1.00 per MMBTU change in natural gas prices would increase or decrease our natural gas costs by approximately $75.0 million to $95.0 million.
Compliance Program Price Risk
We are exposed to market risks related to our obligations to buy and the volatility in the price of credits needed to comply with various governmental and regulatory compliance programs, which includes RINs, required to comply with the Renewable Fuel Standard.RFS. Our overall RINs obligation is based on a percentage of our domestic shipments of on-road fuels as established by Environmental Protection Agency. To the degree we are unable to blend the required amount of biofuels to satisfy our RINs obligation, we must purchase RINs on the open market. To mitigate the impact of the market risk relating to our obligations on our results of operations and cash flows, we may elect to purchase RINs or other environmental credits as part of our liability management strategy.
In addition, we are exposed to risks associated with complying with federal and state legislative and regulatory measures to address greenhouse gasGHG and other emissions. Requirements to reduce emissions could result in increased costs to operate and maintain our facilities as well as implement and manage new emission controls and programs put in place. For example, in September 2016, the state of California extended AB 32, to reduce greenhouse gas emission targets to 40% below 1990 levels by 2030. Compliance with such emission standards may require the purchase of emission credits or similar instruments.
Certain of these compliance contracts or instruments qualify as derivative instruments. For certain of these contracts, we elect the normal purchase normal sale exception under Accounting Standards Codification 815, Derivatives and Hedging, for such instruments, and therefore do not record these contracts at their fair value.
Interest Rate Risk
TheCurrently, the maximum commitment under our Revolving Credit Facility is $4.3$2.85 billion. Borrowings under the Revolving Credit Facility bear interest either at the Alternative Base Rate plus the Applicable Margin or at the Term SOFR Rate plus the Applicable Margin, all as defined in the Revolving Credit Agreement. At SeptemberJune 30, 2022,2023, we had no outstanding balance in variable interest debt. If this facility was fully drawn, a 1.0% change in the interest rate would increase or decrease our interest expense by approximately $24.0$17.6 million annually.
We also have interest rate exposure in connection with our Third Inventory Intermediation Agreement under which we pay a time value of money charge based on LIBOR.
Credit Risk
We are subject to risk of losses resulting from nonpayment or nonperformance by our counterparties. We continue to closely monitor the creditworthiness of customers to whom we grant credit and establish credit limits in accordance with our credit policy.
Item 4. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
We conducted evaluations under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) and Rule 15d-15(e) under the Securities Exchange Act of 1934 as amended (the “Exchange Act”)) as of SeptemberJune 30, 2022.2023. Based upon these evaluations, as required by Exchange Act Rule 13a-15(b), the principal executive officer and principal financial officer concluded that our disclosure controls and procedures are effective as of SeptemberJune 30, 2022.2023.
Changes in Internal Control Over Financial Reporting
There has been no change in our internal controls over financial reporting during the quarter ended SeptemberJune 30, 20222023 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.
PART II - OTHER INFORMATION
Item 1. Legal Proceedings
On September 27, 2021, DCR received a Notice of Administrative Penalty Assessment and Secretary’s Order from the Delaware Department of Natural Resources and Environmental Control, seeking to impose penalties in the amount of $285,000 related to alleged Title V permit violations occurring in 2019 and 2020. On October 15, 2021, DCR filed a Notice of Appeal before Delaware’s Environmental Appeals Board, contesting the Secretary’s findings and requesting a hearing. On November 2, 2021, the Environmental Appeals Board scheduled a Pre-Hearing Conference for April 8, 2022 and Hearing Date for April 26, 2022. On March 17, 2022, the parties entered into a settlement agreement, pursuant to which DCR did not admit to any of the allegations and denied any liability. DCR has paid an administrative penalty of $250,000 and its appeal has been withdrawn.
In connection with the acquisition of the Torrance refinery and related logistics assets, we assumed certain pre-existing environmental liabilities related to certain environmental remediation obligations to address existing soil and groundwater contamination and monitoring activities, which reflect the estimated cost of the remediation obligations. In addition, in connection with the acquisition of the Torrance refinery and related logistics assets, we purchased a ten-year, $100.0 million environmental insurance policy to insure against unknown environmental liabilities.
On April 17, 2019, we received a NoticeWe currently have multiple outstanding notices of Violationviolation (“NOV”NOVs”) fromissued by regulatory authorities for various alleged regulation and permit violations at our refineries. It is not possible to predict the South Coast Air Quality Management District (“SCAQMD”) relating to Title V deviations alleged to have occurredoutcome of any of these NOVs or the amount of the penalties that will be assessed in second half of 2018 self-reported Title V deviations. In May 2022, the SCAQMD requested that we present a settlement proposal to resolve the NOV. On June 16, 2022, we presented a settlement offer of $456,820 to settle the NOV. On July 22, 2022, the SCAQMD presented a counter proposal of $1.2 million. On August 25, 2022, we presented a counter proposal of $736,845. We are awaiting a response from the SCAQMD.
In connection with self-reported flaring eventsany NOV. If any one or more of them were decided against us, we believe that occurred at the Paulsboro refinery between 2016 and 2020, in October 2021, the New Jersey Department of Environmental Protection (“NJDEP”) initiated discussions with PRC regarding potential penalties for alleged violations related to the self-reported flaring events. Although a formal NOV was not issued, NJDEP issued a calculation sheet of potential penalties, totaling approximately $1.6 million. The refinery challenged certain of those potential penalties, and effective September 26, 2022, the parties executed a settlement agreement for a total civil penalty of $1.0 million, fifty percent of which was paid into a generic NJDEP Supplemental Environmental Project.
As the ultimate outcomes of the matters discussed above are uncertain, we cannot currently estimate the final amount or timing of their resolution but any such amount is not expected to have athere would be no material impacteffect on our financial position, results of operations, or cash flows,liquidity. SEC regulations require us to disclose certain information about proceedings arising under federal, state, or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings will result in monetary sanctions of $300,000 or more. On November 24, 2022, the Martinez refinery experienced a spent catalyst release that is currently being investigated by the Bay Area Air Quality Management District (“BAAQMD”), Contra Costa County (“CCC”), the Department of Justice and the Environmental Protection Agency (“EPA”), and the California Department of Fish and Game. On July 11, 2023, the Martinez refinery experienced an unintentional release of petroleum coke dust and has received inquiries or notices of investigation from the BAAQMD, the California Department of Industrial Relations, Division of Occupational Safety and Health, the CCC, and the EPA. The BAAQMD has issued 29 NOVs relating to the spent catalyst incident to date: 21 for opacity; four for failure to properly operate equipment; one for a public nuisance; one for failure to timely report the nuisance; one for fallout in the community; and one for failure to timely report the fallout. The CCC has issued two NOVs related to the spent catalyst incident. The BAAQMD also issued an NOV relating to the coke incident. No penalties have been assessed with these NOVs but it is reasonable to expect that, individually or in the aggregate.aggregate, the amount of such penalties may exceed $300,000.
On February 17, 2017, in Arnold Goldstein, et al. v. Exxon Mobil Corporation, et al., we and PBF LLC, and our subsidiaries, PBF Western Region LLC and Torrance Refining and the manager of our Torrance refinery along with ExxonMobil were named as defendants in a class action and representative action complaint filed on behalf of Arnold Goldstein, John Covas, Gisela Janette La Bella and others similarly situated. The complaint was filed in the Superior Court of the State of California, County of Los Angeles and alleges negligence, strict liability, ultra-hazardous activity, a continuing private nuisance, a permanent private nuisance, a continuing public nuisance, a permanent public nuisance and trespass resulting from the February 18, 2015 electrostatic precipitator (“ESP”) explosion at the Torrance refinery which was then owned and operated by ExxonMobil. The operation of the Torrance refinery by the PBF entities subsequent to our acquisition in July 2016 is also referenced in the complaint. To the extent that plaintiffs’ claims relate to the ESP explosion, ExxonMobil retained responsibility for any liabilities that would arise from the lawsuit pursuant to the agreement relating to the acquisition of the Torrance refinery. On July 2, 2018, the courtCourt granted leave to plaintiffs to file a Second Amended Complaint alleging groundwater contamination. With the filing of the Second Amended Complaint, plaintiffs added an additional plaintiff, Hany Youssef. On October 15, 2019, the judge granted certification to two limited classes of property owners with Youssef as the sole class
representative and named plaintiff, rejecting two other proposed subclasses based on negligence and on strict liability for ultrahazardous activities. The certified subclasses relate to trespass claims for ground contamination and nuisance for air emissions. On February 5, 2021, our motion for Limited Extension of Discovery Cut-Off and a Motion by plaintiffs for Leave to File Third Amended Complaint were heard by the court.Court. On May 5, 2021, the Court granted plaintiffs leave to amend their complaint for the third time to substitute Navarro for Youssef. On May 12, 2021, plaintiffs filed their Third Amended Complaint (“TAC”) that contained significant changes and new claims, including individual claims, that were not included in the motion for leave to amend plaintiffs presented to the Court. On June 9, 2021, we filed a Motion to Dismiss/Strike the TAC. On June 23,
2021, plaintiffs filed their opposition to our Motion to Dismiss/Strike, to which we filed our reply on July 2, 2021. A hearing on the Motion to Dismiss/Strike the TAC was held on August 2, 2021 and the courtCourt ordered that the TAC be struck and that the parties meet and confer with respect to the complaint. After meeting and conferring, plaintiffs agreed to submit a corrected TAC with changes reflecting the removal of Youssef and the substitution of Navarro as the named Plaintiff. On August 23, 2021, the Court approved the parties’ stipulation to take Navarro’s deposition on September 23, 2021. Also, on August 23, 2021, the Court approved the parties’ stipulation to continue the pretrial dates with the new deadlines. On October 8, 2021, plaintiffs filed their Motion to Appoint Navarro as Class Representative. On October 29, 2021, we filed our opposition to this motion. On November 15, 2021, plaintiffs filed their reply. On February 8, 2022, the Court held a hearing on plaintiff’s Motion to Appoint Navarro as Class Representative but did not act on the motion. Instead, the courtCourt ordered the parties to submit draft orders for the Court’s consideration. After considering the parties’ proposed orders, on July 5, 2022, the Court issued a final order ruling that Plaintiffs’ Motion to Substitute José Navarro as Class Representative was denied and decertifying both of Plaintiffs’ proposed Air and Ground Subclasses. The order provided that the case will proceed with Navarro as the sole plaintiff and required the parties to meet and confer and propose a schedule for the remaining pretrial dates and a trial date. On July 19, 2022, Plaintiff filed a petition with the Ninth Circuit Court of Appeals seeking permission to appeal the District Court’s decertification order finding that Navarro is an inadequate class representative. Our answer to the petition was filed on July 29, 2022. On September 22, 2022, the Ninth Circuit issued an order denying Plaintiffs’ petition for permission to file an interlocutory appeal, confirming that the case will proceed with Navarro as the sole plaintiff. On September 27, 2022, the Plaintiff filed a schedule of pretrial and trial dates with a trial date of July 18, 2023, which was approved by the Court. On January 13, 2023, the Defendants filed a motion for judgment on the pleadings. On January 23, 2023, the Plaintiff filed its opposition to the Defendants’ motion. Defendants’ reply to Plaintiff’s opposition was filed on January 30, 2023. Defendants’ motion was scheduled to be heard by the Court on February 13, 2023. On February 27, 2023, the Court issued an order granting our motion for judgment on the pleadings and dismissed Plaintiff’s trespass claim with prejudice and granted Plaintiff leave to amend his nuisance claims in conformity with the order if he can do so consistent with Rule 11 of the Federal Rules of Civil Procedures. On March 27, 2023, Plaintiff filed a Fourth Amended Complaint (“FAC”) relating to the remaining nuisance claims. On April 7, 2023, we responded to the FAC by filing a motion to dismiss for Plaintiff’s failure to establish standing to bring the nuisance claims. On April 17, 2023, Plaintiff filed its opposition to our motion. On April 24, 2023, we filed our reply to Plaintiff’s opposition. A hearing on our motion was scheduled for May 8, 2023 but, on May 2, 2023, the Court took the hearing on the motion off calendar. On May 23, 2023, the Court denied our motion. Currently, the parties are engaged in discovery and trial is scheduled for January 16, 2024. We presently believe the outcome of this litigation will not have a material impact on our financial position, results of operations, or cash flows.
On September 7, 2021, MRC filed a Verified Petition for Writ of Mandate and Complaint for Declaratory and Injunctive Relief against the Bay Area Air Quality Management District (“BAAQMD”)BAAQMD requesting the Court to declare as invalid, unenforceable, and ultra vires the BAAMQD’s July 21, 2021, adoption of amendments to Regulation 6-5: Particulate Emissions from Refinery Fluidized Catalytic Cracking Units - 2021 Amendment (“Rule 6-5 Amendment.Amendment”). MRC is also seeking a writ of mandate ordering the BAAQMD to vacate and rescind the adoption of the Rule 6-5 Amendment, as well as appropriate declaratory relief, injunctive relief, and reasonable costs incurred by MRC to bring this Petition/Complaint. In the Petition/Complaint MRC alleges that: its feasible alternative Particulate Matter (“PM”) reduction proposal that would achieve significant PM reductions while avoiding the significant costs and environmental impacts of the BAAQMD’s adopted PM limit, was improperly removed from consideration and not presented to the BAAQMD Board when the Rule 6-5 Amendment was adopted with the current PM standard; when adopting the Rule 6-5 Amendment, the BAAQMD flagrantly ignored numerous mandatory requirements of the California Environmental Quality Act (“CEQA”) and the California Health and Safety Code; the BAAQMD’s adoption of the Rule 6-5 Amendment also violated California common law; and these failings render the Rule 6-5 Amendment ultra vires, illegal, and unenforceable. We held mandatory settlement conferences with the BAAQMD on October 27, 2021 and December 15, 2021. We expect another mandatory settlement conferenceOn December 9, 2022, we filed a Motion to be heldAugment/Correct the Administrative Record regarding various documents that the BAAQMD is currently withholding and do not plan to include in 2022. The parties are currently compiling the administrative recordrecord. On December 30, 2022, the
BAAQMD filed its opposition to our motion. On January 12, 2023, we filed our reply to the BAAQMD’s opposition. The hearing on our motion was held on February 2, 2023. At the hearing, although the Court partially denied our motion concerning documents where the BAAQMD asserted the attorney client privilege, the Court held that CEQA places a heavy burden on the BAAQMD in justifying withholding documents based on the deliberative privilege. At the Court’s request, the parties agreed to a process whereby they jointly identified approximately 50 of the withheld/redacted documents for completenessthe Court to review. The Court ruled on those documents on February 22, 2023, ordering full disclosure of two types of documents related to the BAAQMD’s cost-estimates for the rule. In compliance with the Court’s order, in March 2023, the BAAQMD produced additional or less-redacted versions of previously produced documents. On March 27, 2023, the Court entered a stipulation establishing the schedule going forward with the bench trial currently scheduled for September 20, 2023. On May 26, 2023, we filed our opening brief. The BAAQMD’s opposition brief was filed on July 21, 2023 and certification.our reply brief is due August 18, 2023. We presently believe the outcome will not have a material impact on our financial position, results of operations, or cash flows.
The federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (“CERCLA”), also known as “Superfund,” imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current or former owner or operator of the disposal site or sites where the release occurred and companies that disposed of or arranged for the disposal of the hazardous substances. Under CERCLA, such persons may be subject to joint and several liability for investigation and the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. As discussed more fully above, certain of our sites are subject to these laws and we may be held liable for investigation and remediation costs or claims for natural resource damages. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances or other pollutants released into the environment. Analogous state laws impose similar responsibilities and liabilities on responsible parties. In our current normal operations, we have generated waste, some of which falls within the statutory definition of a “hazardous substance” and some of which may have been disposed of at sites that may require cleanup under Superfund.
As the ultimate outcomes of the pending matters discussed above are uncertain, we cannot currently estimate the final amount or timing of their resolution but any such amount is not expected to have a material impact on our financial position, results of operations, or cash flows, individually or in the aggregate.
Item 6. Exhibits
The exhibits listed in the accompanying Exhibit Index are filed or incorporated by reference as part of this report and such Exhibit Index is incorporated herein by reference.
EXHIBIT INDEX | | | | | | | | |
Exhibit
Number | | Description |
| | |
| | Second Amended and Restated Employment Agreement dated as of May 3, 2023 between Thomas J. Nimbley and PBF Investments LLC. (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s Current Report on form 8-K dated May 4, 2023 (File No. 001-35764)). |
| | |
| | Third Amended and Restated Employment Agreement dated as of May 3, 2023 between Matthew C. Lucey and PBF Investments LLC. (incorporated by reference to Exhibit 10.2 filed with PBF Energy Inc.'s current report on form 8-K dated May 4, 2023 (File No. 001-35764)). |
| | |
| | Second Amendment to the Third Amended and Restated Inventory Intermediation Agreement dated as of October 25, 2021, among J. Aron & Company LLC, PBF Holding Company LLC, Delaware City Refining Company LLC, Paulsboro Refining Company LLC, and Chalmette Refining, L.L.C, and step-out Agreement (incorporated by reference to Exhibit 10.1 filed with PBF Energy Inc.’s current report on Form 8-K dated June 29, 2023 (File No. 001-35764)). |
| | |
| | List of Guarantor Subsidiaries |
| | |
| | Certification of Thomas J. Nimbley,Matthew C. Lucey, Chief Executive Officer of PBF Holding Company LLC pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
| | |
| | Certification of Erik Young,Karen B. Davis, Chief Financial Officer of PBF Holding Company LLC pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
| | |
| | Certification of Thomas J. Nimbley,Matthew C. Lucey, Chief Executive Officer of PBF Holding Company LLC pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
| | |
| | Certification of Erik Young,Karen B. Davis, Chief Financial Officer of PBF Holding Company LLC pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
| | |
| 101.INS | | Inline XBRL Instance Document. |
| | |
| 101.SCH | | Inline XBRL Taxonomy Extension Schema Document. |
| | |
| 101.CAL | | Inline XBRL Taxonomy Extension Calculation Linkbase Document. |
| | |
| 101.DEF | | Inline XBRL Taxonomy Extension Definition Linkbase Document. |
| | |
| 101.LAB | | Inline XBRL Taxonomy Extension Label Linkbase Document. |
| | |
| 101.PRE | | Inline XBRL Taxonomy Extension Presentation Linkbase Document. |
| | |
| 104 | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). |
—————————— | | | | | |
| * | Filed herewith. |
| † | Indicates management compensatory plan or arrangement. |
| (1) | This exhibit should not be deemed to be “filed” for purposes of Section 18 of the Exchange Act. |
| |
Signatures
Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| | | | | | | | | | | | | | |
| | PBF Holding Company LLC |
| | | | |
| | | | |
| Date: | November 2, 2022August 9, 2023 | | By: | /s/ Erik YoungKaren B. Davis |
| | | | Erik YoungKaren B. Davis
Senior Vice President, Chief Financial Officer
(Duly Authorized Officer and Principal Financial Officer) |
| | | | |
| | PBF Finance Corporation |
| | | | |
| | | | |
| Date: | November 2, 2022August 9, 2023 | | By: | /s/ Erik YoungKaren B. Davis |
| | | | Erik YoungKaren B. Davis
Senior Vice President, Chief Financial Officer
(Duly Authorized Officer and Principal Financial Officer) |